0000066756-22-000014 | 10-K | XBRL Viewer

Change in Benefit Obligation [Roll Forward]

^[1]

12.7

(23.0)

Obligation, Beginning of Year

167.6

149.8

3.6

3.3

$ 3.9

^[2]

4.4

5.0

7.3

Actuarial (Gain) Loss

^[3]

(19.7)

19.2

Participant Contributions

(10.6)

(12.6)

2.9

3.2

Plan Curtailments

0.0

(0.3)

Obligation, End of Year

148.2

167.6

149.8

Change in Plan Assets [Roll Forward]

Fair Value, Beginning of Year

186.0

173.7

Actual Return on Plan Assets

22.8

20.9

Employer Contribution

0.7

0.8

Defined Benefit Plan Contributions by Plan Participants, Excluding Key Employees

2.9

3.2

Funded Status, End of Year

(10.6)

(12.6)

Fair Value, End of Year

201.8

186.0

173.7

53.6

18.4

Non-Current Assets

64.8

34.2

Current Liabilities

(1.4)

(0.6)

Non-Current Liabilities

(9.8)

(15.2)

Accumulated Benefit Obligation

(260.2)

(299.0)

875.5

931.2

Change in Benefit Obligation [Roll Forward]

Obligation, Beginning of Year

965.7

854.0

11.0

10.7

9.3

^[4]

24.6

27.9

31.9

Actuarial (Gain) Loss

^[5]

(39.0)

118.7

Participant Contributions

(56.5)

(54.4)

7.3

8.8

Plan Curtailments

(1.4)

0.0

Obligation, End of Year

911.7

965.7

854.0

Change in Plan Assets [Roll Forward]

Fair Value, Beginning of Year

759.4

699.6

Actual Return on Plan Assets

23.1

93.0

Employer Contribution

^[6]

19.7

21.2

Funded Status, End of Year

(56.5)

(54.4)

Fair Value, End of Year

745.7

759.4

$ 699.6

(166.0)

(206.3)

Current Liabilities

(2.1)

(2.2)

Non-Current Liabilities

$ (163.9)

$ (204.1)

[1]	Excludes gains, losses and contributions associated with irrevocable grantor trusts.
[2]	These components of net periodic postretirement health and life cost are included in the line item “Other” under Other Income (Expense) on the Consolidated Statement of Income.
[3]	Actuarial (gain) loss was primarily the result of increases in discount rates in 2021 compared to decreases in 2020.
[4]	These components of net periodic pension cost are included in the line item “Other” under Other Income (Expense) on the Consolidated Statement of Income.
[5]	Actuarial (gain) loss was primarily the result of increases in discount rates in 2021 compared to decreases in 2020.
[6]	Includes Participant Contributions noted above.

Common Stock and Earnings Per Share

12 Months Ended

Dec. 31, 2021

Equity [Abstract]

Common Stock and Earnings Per Share [Text Block]

COMMON STOCK AND EARNINGS PER SHARE


Summary of Common Stock	Shares	Equity
	Thousands	Millions
Balance as of December 31, 2018	51,509	$1,428.5
Employee Stock Purchase Plan	8	0.7
Invest Direct	38	3.0
Options and Stock Awards	85	1.3
Contributions to RSOP	39	3.2





Balance as of December 31, 2019	51,679	1,436.7
Employee Stock Purchase Plan	13	0.7
Invest Direct	309	18.3
Options and Stock Awards	35	2.2
Contributions to RSOP	49	3.0





Balance as of December 31, 2020	52,085	1,460.9
Employee Stock Purchase Plan	17	0.8
Invest Direct	263	17.5
Options and Stock Awards	49	3.4
Contributions to RSOP	24	3.1
Equity Issuance Program	782	51.0



Balance as of December 31, 2021	53,220	$1,536.7

NOTE 9. COMMON STOCK AND EARNINGS PER SHARE (Continued)

Equity Issuance Program. We entered into a distribution agreement with Lampert Capital Markets, in 2008, as amended most recently in 2020, with respect to the issuance and sale of up to an aggregate of 13.6 million shares of our common stock, without par value, of which 2.1 million shares remain available for issuance as of December 31, 2021. For the year ended December 31, 2021, 0.8 million shares of common stock were issued under this agreement (none in 2020 and 2019) resulting in proceeds of $51.0 million.

Earnings Per Share. We compute basic earnings per share using the weighted average number of shares of common stock outstanding during each period. The difference between basic and diluted earnings per share, if any, arises from non-vested restricted stock units and performance share awards granted under our Executive Long-Term Incentive Compensation Plan.


Reconciliation of Basic and Diluted
Earnings Per Share		Dilutive
Year Ended December 31	Basic	Securities	Diluted
Millions Except Per Share Amounts
2021
Net Income Attributable to ALLETE	$169.2		$169.2
Average Common Shares	52.4	0.1	52.5
Earnings Per Share	$3.23		$3.23

2020
Net Income Attributable to ALLETE	$174.2		$174.2
Average Common Shares	51.9	—	51.9
Earnings Per Share	$3.36		$3.35

2019
Net Income Attributable to ALLETE	$185.6		$185.6
Average Common Shares	51.6	0.1	51.7
Earnings Per Share	$3.59		$3.59

The entire disclosure for shareholders' equity comprised of portions attributable to the parent entity and noncontrolling interest, including other comprehensive income. Includes, but is not limited to, balances of common stock, preferred stock, additional paid-in capital, other capital and retained earnings, accumulated balance for each classification of other comprehensive income and amount of comprehensive income.

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Summary of Common Stock [Table Text Block]

Commitments, Guarantees and Contingencies - Environmental Matters (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Coal Combustion Residuals [Member]
Environmental Matters [Line Items]
Expected Period for Costs of Compliance	15 years
Coal Combustion Residuals [Member] \| Minimum [Member]
Environmental Matters [Line Items]
Estimated Costs of Compliance	$ 65
Coal Combustion Residuals [Member] \| Maximum [Member]
Environmental Matters [Line Items]
Estimated Costs of Compliance	120
Manufactured Gas Plant [Member] \| Superior, WI [Member]
Environmental Matters [Line Items]
Estimated Costs of Compliance (Accrued)	$ 18	$ 7

Common Stock and Earnings Per Share (Tables)

12 Months Ended

Dec. 31, 2021

Equity [Abstract]


Summary of Common Stock	Shares	Equity
	Thousands	Millions
Balance as of December 31, 2018	51,509	$1,428.5
Employee Stock Purchase Plan	8	0.7
Invest Direct	38	3.0
Options and Stock Awards	85	1.3
Contributions to RSOP	39	3.2





Balance as of December 31, 2019	51,679	1,436.7
Employee Stock Purchase Plan	13	0.7
Invest Direct	309	18.3
Options and Stock Awards	35	2.2
Contributions to RSOP	49	3.0





Balance as of December 31, 2020	52,085	1,460.9
Employee Stock Purchase Plan	17	0.8
Invest Direct	263	17.5
Options and Stock Awards	49	3.4
Contributions to RSOP	24	3.1
Equity Issuance Program	782	51.0



Balance as of December 31, 2021	53,220	$1,536.7

Reconciliation of Basic and Diluted Earnings Per Share [Table Text Block]


Reconciliation of Basic and Diluted
Earnings Per Share		Dilutive
Year Ended December 31	Basic	Securities	Diluted
Millions Except Per Share Amounts
2021
Net Income Attributable to ALLETE	$169.2		$169.2
Average Common Shares	52.4	0.1	52.5
Earnings Per Share	$3.23		$3.23

2020
Net Income Attributable to ALLETE	$174.2		$174.2
Average Common Shares	51.9	—	51.9
Earnings Per Share	$3.36		$3.35

2019
Net Income Attributable to ALLETE	$185.6		$185.6
Average Common Shares	51.6	0.1	51.7
Earnings Per Share	$3.59		$3.59

Commitments, Guarantees and Contingencies (Tables)

12 Months Ended

Dec. 31, 2021

Commitments and Contingencies Disclosure [Abstract]

Estimated Minimum Annual Payments for Certain Long-Term Commitments [Table Text Block]

The following table details the estimated minimum payments for certain long-term commitments:


As of December 31, 2021
Millions	2022	2023	2024	2025	2026	Thereafter

Capital Purchase Obligations	$50.7	$0.1	—	—	—	—
Easements (a)	$8.2	$8.4	$8.4	$8.8	$9.2	$239.7
PPAs (b)	$141.1	$140.7	$133.5	$131.4	$138.3	$1,060.6
Other Purchase Obligations (c)	$58.9	$22.5	$23.1	—	—	—

(a)Easement obligations represent the minimum payments for our land easement agreements at our wind energy facilities.

(b)Does not include the agreement with Manitoba Hydro expiring in 2022, as this contract is for surplus energy only; or the Oliver Wind I, Oliver Wind II or Nobles 2 PPAs, as Minnesota Power only pays for energy as it is delivered. (See Power Purchase Agreements.)

(c)Consists of long-term service agreements for wind energy facilities and minimum purchase commitments under coal and rail contracts.

Minnesota Power has also entered into the following long-term PPAs for the purchase of capacity and energy as of December 31, 2021:

Counterparty

Quantity

Product

Commencement

Expiration

Pricing

PPAs

Calpine Corporation

25 MW

Capacity

June 2019

May 2026

Fixed

Manitoba Hydro

PPA 1

(a)

Energy

May 2011

April 2022

Forward Market Prices

PPA 2

250 MW

Capacity / Energy

June 2020

May 2035

(b)

PPA 3

133 MW

Energy

June 2020

June 2040

Forward Market Prices

Nobles 2

250 MW

Capacity / Energy

December 2020

December 2040

Fixed

Oliver Wind I

(c)

Energy

December 2006

December 2040

Fixed

Oliver Wind II

(c)

Energy

December 2007

December 2040

Fixed

(a)The energy purchased consists primarily of surplus hydro energy on Manitoba Hydro's system and is delivered on a non-firm basis. Minnesota Power will purchase at least one million MWh of energy over the contract term.

(b)The capacity price was adjusted annually until 2020 by the change in a governmental inflationary index. The energy price is based on a formula that includes an annual fixed component adjusted for the change in a governmental inflationary index and a natural gas index, as well as market prices.

(c)The PPAs provide for the purchase of all output from the 50 MW Oliver Wind I and 48 MW Oliver Wind II wind energy facilities.

Minnesota Power has also entered into the following long-term PSAs for the sale of capacity and energy as of December 31, 2021:

Counterparty

Quantity

Product

Commencement

Expiration

Pricing

PSAs

Basin

PSA 1

(a)

Capacity

June 2022

May 2025

Fixed

PSA 2

100 MW

Capacity

June 2025

May 2028

Fixed

Great River Energy

100 MW

Capacity

June 2022

May 2025

Fixed

Minnkota Power

(b)

Capacity / Energy

June 2014

December 2026

(b)

Oconto Electric Cooperative

25 MW

Capacity / Energy

January 2019

May 2026

Fixed

Silver Bay Power

(c)

Energy

January 2017

December 2031

(d)

(a)The agreement provides for 75 MW of capacity from June 1, 2022, through May 31, 2023, and increases to 125 MW of capacity from June 1, 2023, through May 31, 2025.

(b)Minnesota Power is selling a portion of its entitlement from Square Butte to Minnkota Power, resulting in Minnkota Power’s net entitlement increasing and Minnesota Power’s net entitlement decreasing until Minnesota Power’s share is eliminated at the end of 2025. Of Minnesota Power’s 50 percent output entitlement, it sold to Minnkota Power approximately 28 percent in 2021 (28 percent in 2020 and in 2019). (See Square Butte PPA.)

(c)Silver Bay Power supplies approximately 90 MW of load to Northshore Mining, an affiliate of Silver Bay Power, which had previously been served predominately through self-generation by Silver Bay Power. Minnesota Power now supplies the full energy requirements for Silver Bay Power.

(d)The energy pricing escalates at a fixed rate annually and is adjusted for changes in a natural gas index.

Pension and Other Postretirement Benefit Plans - Recurring Fair Value Measures, Activity in Level 3 (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Pension [Member]
Activity in Level 3 [Roll Forward]
Fair Value, Beginning of Year	$ 759.4	$ 699.6
Fair Value, End of Year	745.7	759.4
Pension [Member] \| Level 3 [Member]
Activity in Level 3 [Roll Forward]
Fair Value, Beginning of Year	25.0
Fair Value, End of Year	21.6	25.0
Pension [Member] \| Private Equity [Member]
Activity in Level 3 [Roll Forward]
Fair Value, Beginning of Year	7.0
Fair Value, End of Year	0.0	7.0
Pension [Member] \| Private Equity [Member] \| Level 3 [Member]
Activity in Level 3 [Roll Forward]
Fair Value, Beginning of Year	7.0	8.0
Defined Benefit Plan, Plan Assets Level 3 Reconciliation, Increase (Decrease) for Actual Return (Loss) on Plan Assets Still Held	(3.5)	0.1
Defined Benefit Plan, Plan Assets Level 3 Reconciliation, Increase (Decrease) for Purchase, Sale, and Settlement	(3.5)	(1.1)
Fair Value, End of Year	0.0	7.0
Pension [Member] \| Real Estate [Member]
Activity in Level 3 [Roll Forward]
Fair Value, Beginning of Year	18.0
Fair Value, End of Year	21.6	18.0
Pension [Member] \| Real Estate [Member] \| Level 3 [Member]
Activity in Level 3 [Roll Forward]
Fair Value, Beginning of Year	18.0	18.0
Defined Benefit Plan, Plan Assets Level 3 Reconciliation, Increase (Decrease) for Actual Return (Loss) on Plan Assets Still Held	3.6	0.0
Defined Benefit Plan, Plan Assets Level 3 Reconciliation, Increase (Decrease) for Purchase, Sale, and Settlement	0.0	0.0
Fair Value, End of Year	21.6	18.0
Postretirement Health and Life [Member]
Activity in Level 3 [Roll Forward]
Fair Value, Beginning of Year	186.0	173.7
Fair Value, End of Year	201.8	186.0
Postretirement Health and Life [Member] \| Level 3 [Member]
Activity in Level 3 [Roll Forward]
Fair Value, Beginning of Year	1.7
Fair Value, End of Year	2.0	1.7
Postretirement Health and Life [Member] \| Private Equity [Member]
Activity in Level 3 [Roll Forward]
Fair Value, Beginning of Year	1.7
Fair Value, End of Year	2.0	1.7
Postretirement Health and Life [Member] \| Private Equity [Member] \| Level 3 [Member]
Activity in Level 3 [Roll Forward]
Fair Value, Beginning of Year	1.7	1.7
Defined Benefit Plan, Plan Assets Level 3 Reconciliation, Increase (Decrease) for Actual Return (Loss) on Plan Assets Still Held	0.8	0.0
Defined Benefit Plan, Plan Assets Level 3 Reconciliation, Increase (Decrease) for Purchase, Sale, and Settlement	(0.5)	0.0
Fair Value, End of Year	$ 2.0	$ 1.7

Amount of asset segregated and restricted to provide benefit under defined benefit plan. Asset includes, but is not limited to, stock, bond, other investment, earning from investment, and contribution by employer and employee.

Selected Quarterly Financial Information [Abstract]

Pension and Other Postretirement Benefit Plans - Estimated Future Benefit Payments (Details) $ in Millions	Dec. 31, 2021 USD ($)
Pension [Member]
Estimated Future Benefit Payments [Abstract]
2022	$ 54.6
2023	54.4
2024	54.4
2025	53.8
2026	53.1
Years 2027 - 2031	257.2
Postretirement Health and Life [Member]
Estimated Future Benefit Payments [Abstract]
2022	8.4
2023	8.4
2024	8.4
2025	8.2
2026	8.1
Years 2027 - 2031	$ 41.6

Consolidated Statement of Income - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating Revenue [Abstract]
Contracts with Customers – Utility	$ 1,227.9	$ 987.3	$ 1,042.4
Contracts with Customers – Non-utility	179.9	170.5	186.5
Other – Non-utility	11.4	11.3	11.6
Total Operating Revenue	1,419.2	1,169.1	1,240.5
Operating Expenses [Abstract]
Fuel, Purchased Power and Gas - Utility	562.4	358.6	390.7
Transmission Services - Utility	75.3	67.0	69.8
Cost of Sales - Non-utility	68.8	66.7	80.6
Operating and Maintenance	259.2	252.0	264.3
Depreciation and Amortization	231.7	217.8	202.0
Taxes Other than Income Taxes	70.5	56.1	53.3
Total Operating Expenses	1,267.9	1,018.2	1,060.7
Operating Income	151.3	150.9	179.8
Other Income (Expense) [Abstract]
Interest Expense	(69.1)	(65.6)	(64.9)
Equity Earnings	20.0	22.1	21.7
Gain on Sale of U.S. Water Services	0.0	0.0	23.6
Other	8.7	14.7	18.7
Total Other Expense	(40.4)	(28.8)	(0.9)
Income Before Non-Controlling Interest and Income Taxes	110.9	122.1	178.9
Income Tax Benefit	(26.9)	(39.5)	(6.6)
Net Income	137.8	161.6	185.5
Net Loss Attributable to Non-Controlling Interest	(31.4)	(12.6)	(0.1)
Net Income Attributable to ALLETE	$ 169.2	$ 174.2	$ 185.6
Average Shares of Common Stock and Per Share Data [Abstract]
Basic (Shares)	52.4	51.9	51.6
Diluted (Shares)	52.5	51.9	51.7
Basic Earnings Per Share of Common Stock	$ 3.23	$ 3.36	$ 3.59
Diluted Earnings Per Share of Common Stock	$ 3.23	$ 3.35	$ 3.59

Quarterly Financial Data (Unaudited) (Tables)

12 Months Ended

Dec. 31, 2021

Quarterly Financial Data (Unaudited) [Table Text Block]


Quarter Ended	Mar. 31	Jun. 30	Sept. 30	Dec. 31
Millions Except Earnings Per Share
2021
Operating Revenue	$339.2	$335.6	$345.4	$399.0
Operating Income	$42.0	$28.2	$31.1	$50.0
Net Income Attributable to ALLETE	$51.8	$27.9	$27.6	$61.9
Earnings Per Share of Common Stock
Basic	$0.99	$0.53	$0.53	$1.18
Diluted	$0.99	$0.53	$0.53	$1.18
2020
Operating Revenue	$311.6	$243.2	$293.9	$320.4
Operating Income	$60.2	$12.7	$41.6	$36.4
Net Income Attributable to ALLETE	$66.3	$20.1	$40.7	$47.1
Earnings Per Share of Common Stock
Basic	$1.28	$0.39	$0.78	$0.91
Diluted	$1.28	$0.39	$0.78	$0.90
2019
Operating Revenue	$357.2	$290.4	$288.3	$304.6
Operating Income	$56.8	$36.2	$37.0	$49.8
Net Income Attributable to ALLETE	$70.5	$34.2	$31.2	$49.7
Earnings Per Share of Common Stock
Basic	$1.37	$0.66	$0.60	$0.96
Diluted	$1.37	$0.66	$0.60	$0.96

Pension and Other Postretirement Benefit Plans - Reconciliation of Net Postretirement Health and Life Amounts Recognized in Consolidated Balance Sheet (Details) - Postretirement Health and Life [Member] - USD ($)
$ in Millions

Dec. 31, 2021

Dec. 31, 2020

Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]

^[1]

$ 12.7

$ (23.0)

Accumulated Net Periodic Benefit Cost in Excess of Contributions

20.7

28.3

20.2

13.1

Total Net Postretirement Health and Life Amounts Recognized in Consolidated Balance Sheet

$ 53.6

$ 18.4

[1]	Excludes gains, losses and contributions associated with irrevocable grantor trusts.

Operations and Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2021

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Cash, Cash Equivalents and Restricted Cash [Table Text Block]


Cash, Cash Equivalents and Restricted Cash
As of December 31	2021	2020	2019
Millions
Cash and Cash Equivalents	$45.1	$44.3	$69.3
Restricted Cash included in Prepayments and Other	0.3	0.8	2.8
Restricted Cash included in Other Non-Current Assets	2.3	20.1	20.4
Cash, Cash Equivalents and Restricted Cash on the Consolidated Statement of Cash Flows	$47.7	$65.2	$92.5

Supplemental Statement of Cash Flow Information [Table Text Block]

Supplemental Statement of Cash Flow Information.


Consolidated Statement of Cash Flows
Year Ended December 31	2021	2020	2019
Millions
Cash Paid During the Period for Interest – Net of Amounts Capitalized	$66.8	$62.0	$63.5
Recognition of Right-of-use Assets and Lease Liabilities (a)	—	—	28.7





Noncash Investing and Financing Activities
Increase (Decrease) in Accounts Payable for Capital Additions to Property, Plant and Equipment	$(14.0)	$(67.0)	$33.9
Reclassification of Redeemable Non-Controlling Interest to Current Liabilities (b)	$30.6	—	—
Capitalized Asset Retirement Costs	$16.9	$4.1	$20.7


AFUDC–Equity	$2.6	$1.9	$2.3

(a)Amount of the right-of-use asset and lease liability recognized with the adoption of an accounting standards update for leases.

(b)Amount reclassified to Current Liabilities resulting from the exercise of an option to buy out a non-controlling interest.

Accounts Receivable [Table Text Block]


Accounts Receivable
As of December 31	2021	2020
Millions
Trade Accounts Receivable
Billed	$100.8	$93.5
Unbilled	24.7	20.9
Less: Allowance for Doubtful Accounts	1.8	2.5


Total Accounts Receivable	$123.7	$111.9

Inventories – Net [Table Text Block]


Inventories – Net
As of December 31	2021	2020
Millions
Fuel (a)	$18.7	$23.1
Materials and Supplies	56.1	51.1
Construction of Wind Energy Facilities (b)	22.9	—




Total Inventories – Net	$97.7	$74.2

(a) Fuel consists primarily of coal inventory at Minnesota Power.

(b) Project costs related to ALLETE Clean Energy’s Northern Wind and Red Barn wind projects which are expected be sold in late 2022 and 2023, respectively. (See Other Current Liabilities.)

Other Non-Current Assets [Table Text Block]


Other Non-Current Assets
As of December 31	2021	2020
Millions
Contract Assets (a)	$23.3	$25.5

Operating Lease Right-of-use Assets	16.4	22.4
ALLETE Properties	19.4	18.2
Restricted Cash	2.3	20.1
Other Postretirement Benefit Plans	64.8	34.2
Other	87.5	86.4
Total Other Non-Current Assets	$213.7	$206.8

(a) Contract Assets include payments made to customers as an incentive to execute or extend service agreements. The contract payments are being amortized over the term of the respective agreements as a reduction to revenue.

Other Current Liabilities [Table Text Block]


Other Current Liabilities
As of December 31	2021	2020
Millions
Customer Deposits (a)	$27.2	$7.4
PSAs	12.6	12.5



Manufactured Gas Plant (b)	12.8	—
Fuel Adjustment Clause	5.0	3.7
Operating Lease Liabilities	4.8	5.9
Redeemable Non-Controlling Interest (c)	30.6	—
Other	40.0	37.2
Total Other Current Liabilities	$133.0	$66.7

(a) Primarily related to deposits received by ALLETE Clean Energy for the Northern Wind and Red Barn wind projects which are expected be sold in late 2022 and 2023 respectively. (See Inventories – Net.)

(b) The manufactured gas plant represents the current liability for remediation of a former manufactured gas plant site located in Superior, Wisconsin, and formerly operated by SWL&P. (See Note 8. Commitments, Guarantees and Contingencies.)

(c) Amount reclassified from Non-Controlling Interest in Subsidiaries resulting from the exercise of an option to buy out a non-controlling interest, which was paid in the first quarter of 2022.

Other Non-Current Liabilities [Table Text Block]


Other Non-Current Liabilities
As of December 31	2021	2020
Millions
Asset Retirement Obligation	$184.5	$166.6
PSAs	39.5	52.1
Operating Lease Liabilities	11.6	16.5
Other	45.2	50.1
Total Other Non-Current Liabilities	$280.8	$285.3

Lease, Cost [Table Text Block]

Additional information on the components of lease cost and presentation of cash flows were as follows:


As December 31	2021	2020
Millions
Operating Lease Cost	$6.7	$8.3

Other Information:
Operating Cash Flows From Operating Leases	$6.7	$8.3

Additional information related to leases was as follows:


As of December 31	2021		2020
Millions

Balance Sheet Information Related to Leases:
Other Non-Current Assets	$16.4		$22.4
Total Operating Lease Right-of-use Assets	$16.4		$22.4

Other Current Liabilities	$4.8		$5.9
Other Non-Current Liabilities	11.6		16.5
Total Operating Lease Liabilities	$16.4		$22.4

Weighted Average Remaining Lease Term (Years):
Operating Leases - Vehicles and Equipment	3		3
Operating Leases - Land and Other	27		27

Weighted Average Discount Rate:
Operating Leases - Vehicles and Equipment	3.8	%	3.1	%
Operating Leases - Land and Other	4.5	%	4.1	%

Lessee, Operating Lease, Liability, Maturity [Table Text Block]

Maturities of lease liabilities were as follows:


												December 31, 2021
Millions
2022												$5.1
2023												3.3
2024												3.0
2025												2.8
2026												2.8
Thereafter												5.0
Total Lease Payments Due												22.0
Less: Imputed Interest												5.6
Total Lease Obligations												16.4
Less: Current Lease Obligations												4.8
Total Long-term Lease Obligations												$11.6

Other Income (Expense) - Other [Table Text Block]


Other Income (Expense) - Other
Year Ended December 31	2021	2020	2019
Millions
Pension and Other Postretirement Benefit Plan Non-Service Credit (a)	$6.1	$8.6	$7.7
Interest and Investment Earnings	2.3	1.6	4.4
AFUDC - Equity	2.6	1.9	2.3
Gain on Land Sales	0.1	0.4	2.1
Other	(2.4)	2.2	2.2
Total Other Income (Expense) - Other	$8.7	$14.7	$18.7

(a)These are components of net periodic pension and other postretirement benefit cost other than service cost. (See Note 11. Pension and Other Postretirement Benefit Plans.)

Property, Plant and Equipment (Tables)

12 Months Ended

Dec. 31, 2021

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment and Estimated Useful Lives of Property, Plant and Equipment [Table Text Block]


Property, Plant and Equipment
As of December 31	2021	2020
Millions
Regulated Operations
Property, Plant and Equipment in Service	$5,028.7	$4,972.3

Construction Work in Progress	108.7	79.4
Accumulated Depreciation	(1,834.6)	(1,758.0)
Regulated Operations – Net	3,302.8	3,293.7
ALLETE Clean Energy
Property, Plant and Equipment in Service	1,716.9	1,275.4
Construction Work in Progress	79.9	261.0
Accumulated Depreciation	(149.0)	(112.9)
ALLETE Clean Energy – Net	1,647.8	1,423.5






Corporate and Other (a)
Property, Plant and Equipment in Service	267.1	240.5
Construction Work in Progress	19.8	9.6
Accumulated Depreciation	(137.3)	(126.5)
Corporate and Other – Net	149.6	123.6
Property, Plant and Equipment – Net	$5,100.2	$4,840.8

(a)Primarily includes BNI Energy and a small amount of non-rate base generation.

Estimated Useful Lives of Property, Plant and Equipment (Years)

Regulated Operations

Generation

2 to 50

ALLETE Clean Energy

5 to 35

Transmission

50 to 75

Corporate and Other

3 to 50

Distribution

18 to 70

Asset Retirement Obligations [Table Text Block]


Asset Retirement Obligations
Millions
Obligation as of December 31, 2019						$160.3
Accretion						8.3
Liabilities Recognized						1.4
Liabilities Settled						(3.6)
Revisions in Estimated Cash Flows						0.2
Obligation as of December 31, 2020						166.6
Accretion						8.8
Liabilities Recognized						4.5
Liabilities Settled						(5.2)
Revisions in Estimated Cash Flows						9.8
Obligation as of December 31, 2021						$184.5

Consolidated Statement of Comprehensive Income Parentheticals - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Statement of Comprehensive Income [Abstract]
Unrealized Gain (Loss) on Securities, Income Tax Expense (Benefit)	$ (0.1)	$ 0.1	$ 0.1
Defined Benefit Pension and Other Postretirement Benefit Plans, Income Tax Expense (Benefit)	$ 3.0	$ (3.1)	$ 1.4

Employee Stock and Incentive Plans - Employee Stock Ownership Plan (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Employee Stock Ownership Plan [Abstract]
ESOP Compensation Expense	$ 11.5	$ 11.2	$ 10.8

Pension and Other Postretirement Benefit Plans - Other Changes in Plan Assets and Benefit Obligations Recognized in Other Comprehensive Income and Regulatory Assets or Liabilities (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Other Postretirement Benefits Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Net (Gain) Loss	$ (32.7)	$ 8.1
Amortization of Prior Service Cost	7.6	8.0
Amortization of Loss	(3.0)	(1.0)
Total Recognized in Other Comprehensive Income and Regulatory Assets or Liabilities	(28.1)	15.1
Pension [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Net (Gain) Loss	(20.1)	68.4
Amortization of Prior Service Cost	0.2	0.2
Amortization of Loss	(18.8)	(12.8)
Total Recognized in Other Comprehensive Income and Regulatory Assets or Liabilities	$ (38.7)	$ 55.8

Equity Investments

12 Months Ended

Dec. 31, 2021

Equity Method Investments and Joint Ventures [Abstract]

Equity Investments [Text Block]

EQUITY INVESTMENTS

Investment in ATC. Our wholly-owned subsidiary, ALLETE Transmission Holdings, owns approximately 8 percent of ATC, a Wisconsin-based utility that owns and maintains electric transmission assets in portions of Wisconsin, Michigan, Minnesota and Illinois. We account for our investment in ATC under the equity method of accounting. On January 31, 2022, we invested an additional $2.7 million in ATC. In total, we expect to invest approximately $6.0 million in 2022.


ALLETE’s Investment in ATC
Year Ended December 31	2021	2020
Millions
Equity Investment Beginning Balance	$149.0	$141.6
Cash Investments	—	2.7
Equity in ATC Earnings	21.3	22.3
Distributed ATC Earnings	(17.2)	(18.9)

Amortization of the Remeasurement of Deferred Income Taxes	1.4	1.3
Equity Investment Ending Balance	$154.5	$149.0


ATC Summarized Financial Data
Balance Sheet Data
As of December 31	2021	2020
Millions
Current Assets	$89.8	$92.8
Non-Current Assets	5,628.1	5,400.5
Total Assets	$5,717.9	$5,493.3
Current Liabilities	$436.9	$310.8
Long-Term Debt	2,513.0	2,512.2
Other Non-Current Liabilities	422.0	378.2
Members’ Equity	2,346.0	2,292.1
Total Liabilities and Members’ Equity	$5,717.9	$5,493.3


Income Statement Data
Year Ended December 31	2021	2020	2019
Millions
Revenue	$754.8	$758.1	$744.4
Operating Expense	376.2	372.4	373.5
Other Expense	113.9	110.9	110.5
Net Income	$264.7	$274.8	$260.4
ALLETE’s Equity in Net Income	$21.3	$22.3	$21.7

ATC’s authorized return on equity is 10.02 percent, or 10.52 percent including an incentive adder for participation in a regional transmission organization, based on a 2020 FERC order that granted rehearing of a 2019 FERC order. These FERC orders are subject to various outstanding legal challenges related to the refund period ordered by the FERC. If these legal challenges are successful, ATC may be required to provide refunds to its customers of up to approximately $65 million of which our share would be approximately $5 million pre-tax. In addition, the FERC issued a Notice of Proposed Rulemaking in April 2021 proposing to limit the 50 basis point incentive adder for participation in a regional transmission organization to only the first three years of membership in such an organization. If this proposal is adopted, our equity in earnings from ATC would be reduced by approximately $1 million pre-tax annually.

NOTE 5. EQUITY INVESTMENTS (Continued)

Investment in Nobles 2. Our subsidiary, ALLETE South Wind, owns a 49 percent equity interest in Nobles 2, the entity that owns and operates a 250 MW wind energy facility in southwestern Minnesota pursuant to a 20-year PPA with Minnesota Power. We account for our investment in Nobles 2 under the equity method of accounting.


ALLETE’s Investment in Nobles 2
Millions
Equity Investment Balance as of December 31, 2020			$152.2
Cash Investments			17.6
Equity in Nobles 2 Earnings (a)			(1.3)
Distributed Nobles 2 Earnings			(5.0)
Equity Investment Balance as of December 31, 2021			$163.5

(a)The Company also recorded net loss attributable to non-controlling interest of $6.6 million related to its investment in Nobles 2.

Operations and Significant Accounting Policies - Non-Controlling Interest (Details)	12 Months Ended
	Dec. 31, 2021 MW
Glen Ullin Energy Center [Member]
Non-Controlling Interest Details [Line Items]
Generating Capacity Subject to Tax Equity Financing	106
South Peak [Member]
Non-Controlling Interest Details [Line Items]
Generating Capacity Subject to Tax Equity Financing	80
Diamond Spring [Member]
Non-Controlling Interest Details [Line Items]
Generating Capacity Subject to Tax Equity Financing	303
Caddo [Member]
Non-Controlling Interest Details [Line Items]
Generating Capacity Subject to Tax Equity Financing	303
Nobles 2 [Member]
Non-Controlling Interest Details [Line Items]
Generating Capacity Subject to Tax Equity Financing	250

Operations and Significant Accounting Policies - Supplemental Statement of Cash Flow Information - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2021

Dec. 31, 2020

Dec. 31, 2019

Supplemental Cash Flow Information [Abstract]

Cash Paid During the Period for Interest – Net of Amounts Capitalized

$ 66.8

$ 62.0

$ 63.5

Recognition of Right-of-use Assets and Lease Liabilities

^[1]

0.0

28.7

Noncash Investing and Financing Activities [Abstract]

Increase (Decrease) in Accounts Payable for Capital Additions to Property, Plant and Equipment

(14.0)

(67.0)

33.9

Reclassification of Redeemable Non-Controlling Interest to Current Liabilities

^[2]

30.6

0.0

Capitalized Asset Retirement Costs

16.9

4.1

20.7

AFUDC–Equity

$ 2.6

$ 1.9

$ 2.3

[1]	Amount of the right-of-use asset and lease liability recognized with the adoption of an accounting standards update for leases.
[2]	Amount reclassified to Current Liabilities resulting from the exercise of an option to buy out a non-controlling interest.

Short-Term and Long-Term Debt

12 Months Ended

Dec. 31, 2021

Debt Disclosure [Abstract]

Short-Term and Long-Term Debt [Text Block]

SHORT-TERM AND LONG-TERM DEBT

Short-Term Debt. As of December 31, 2021, total short-term debt outstanding was $214.2 million ($203.7 million as of December 31, 2020), and consisted of long-term debt due within one year and included $0.2 million of unamortized debt issuance costs.

As of December 31, 2021, we had consolidated bank lines of credit aggregating $432.0 million ($407.0 million as of December 31, 2020), most of which expire in January 2025. We had $31.5 million outstanding in standby letters of credit and $159.7 million outstanding draws under our lines of credit as of December 31, 2021 ($22.3 million in standby letters of credit and no outstanding draws as of December 31, 2020).

NOTE 7. SHORT-TERM AND LONG-TERM DEBT (Continued)

Long-Term Debt. As of December 31, 2021, total long-term debt outstanding was $1,763.2 million ($1,593.2 million as of December 31, 2020) and included $8.8 million of unamortized debt issuance costs. The aggregate amount of long-term debt maturing in 2022 is $214.5 million; $89.7 million in 2023; $74.4 million in 2024; $386.7 million in 2025; $77.2 million in 2026; and $1,143.9 million thereafter. Substantially all of our regulated electric plant is subject to the lien of the mortgages collateralizing outstanding first mortgage bonds. The mortgages contain non-financial covenants customary in utility mortgages, including restrictions on our ability to incur liens, dispose of assets, and merge with other entities.

Minnesota Power is obligated to make financing payments for the Camp Ripley solar array totaling $1.4 million annually during the financing term, which expires in 2027. Minnesota Power has the option at the end of the financing term to renew for a two‑year term, or to purchase the solar array for approximately $4 million. Minnesota Power anticipates exercising the purchase option when the term expires.

On March 25, 2021, ALLETE entered into a $150 million unsecured term loan agreement (Term Loan). An additional draw of $35 million through the exercise of an accordion feature was made during the second quarter of 2021. As of September 30, 2021, we have borrowed the full amount of $185 million. The Term Loan is due March 24, 2022, and may be repaid at any time. Interest is payable monthly at a rate per annum equal to LIBOR plus 0.75 percent. Proceeds from the Term Loan were used for general corporate purposes.

On September 1, 2021, ALLETE issued $100 million of its First Mortgage Bonds (Bonds) to certain institutional buyers in the private placement market. The Bonds, which bear interest at 2.79 percent, will mature in September 2031 and pay interest semi-annually in March and September of each year, commencing on March 1, 2022. ALLETE has the option to prepay all or a portion of the Bonds at its discretion, subject to a make-whole provision. The Bonds are subject to additional terms and conditions which are customary for these types of transactions. Proceeds from the sale of the Bonds were used to fund utility capital investment and for general corporate purposes. The Bonds were sold in reliance on an exemption from registration under Section 4(a)(2) of the Securities Act of 1933, as amended, to institutional accredited investors.

In January 2022, ALLETE Clean Energy received approximately $183.0 million from final closing of tax equity funding for the Caddo wind energy facility. The proceeds from the funding were used to pay down a portion of outstanding draws on our lines of credit.

NOTE 7. SHORT-TERM AND LONG-TERM DEBT (Continued)

Long-Term Debt (Continued)


Long-Term Debt
As of December 31	2021	2020
Millions
First Mortgage Bonds
4.85% Series Due 2021	—	$15.0
3.02% Series Due 2021	—	60.0
3.40% Series Due 2022	$75.0	75.0
6.02% Series Due 2023	75.0	75.0
3.69% Series Due 2024	60.0	60.0
4.90% Series Due 2025	30.0	30.0
5.10% Series Due 2025	30.0	30.0
3.20% Series Due 2026	75.0	75.0
5.99% Series Due 2027	60.0	60.0
3.30% Series Due 2028	40.0	40.0
4.08% Series Due 2029	70.0	70.0
3.74% Series Due 2029	50.0	50.0
2.50% Series Due 2030	46.0	46.0
3.86% Series Due 2030	60.0	60.0
2.79% Series Due 2031	100.0	—
5.69% Series Due 2036	50.0	50.0
6.00% Series Due 2040	35.0	35.0
5.82% Series Due 2040	45.0	45.0
4.08% Series Due 2042	85.0	85.0
4.21% Series Due 2043	60.0	60.0
4.95% Series Due 2044	40.0	40.0
5.05% Series Due 2044	40.0	40.0
4.39% Series Due 2044	50.0	50.0
4.07% Series Due 2048	60.0	60.0
4.47% Series Due 2049	30.0	30.0
3.30% Series Due 2050	94.0	94.0


ALLETE Clean Energy Unsecured Term Loan Variable Rate Due 2021	—	65.0
Armenia Mountain Senior Secured Notes 3.26% Due 2024	29.1	38.6
Industrial Development Variable Rate Demand Refunding Revenue Bonds Series 2006, Due 2025	27.8	27.8
Revolving Credit Facility Variable Rate Due 2025	145.0	—
Senior Unsecured Notes 2.65% Due 2025	150.0	150.0
Senior Unsecured Notes 3.11% Due 2027	80.0	80.0
SWL&P First Mortgage Bonds 4.15% Series Due 2028	15.0	15.0
SWL&P First Mortgage Bonds 4.14% Series Due 2048	12.0	12.0
Unsecured Term Loan Variable Rate Due 2021	—	40.0
Unsecured Term Loan Variable Rate Due 2022	110.0	—
Other Long-Term Debt, 2.16% – 4.58% Due 2022 – 2051	57.5	43.0
Unamortized Debt Issuance Costs	(9.0)	(9.5)
Total Long-Term Debt	1,977.4	1,796.9
Less: Due Within One Year	214.2	203.7
Net Long-Term Debt	$1,763.2	$1,593.2

NOTE 7. SHORT-TERM AND LONG-TERM DEBT (Continued)

Long-Term Debt (Continued)

Financial Covenants. Our long-term debt arrangements contain customary covenants. In addition, our lines of credit and letters of credit supporting certain long-term debt arrangements contain financial covenants. Our compliance with financial covenants is not dependent on debt ratings. The most restrictive financial covenant requires ALLETE to maintain a ratio of indebtedness to total capitalization (as the amounts are calculated in accordance with the respective long-term debt arrangements) of less than or equal to 0.65 to 1.00, measured quarterly. As of December 31, 2021, our ratio was approximately 0.41 to 1.00. Failure to meet this covenant would give rise to an event of default if not cured after notice from the lender, in which event ALLETE may need to pursue alternative sources of funding. Some of ALLETE’s debt arrangements contain “cross-default” provisions that would result in an event of default if there is a failure under other financing arrangements to meet payment terms or to observe other covenants that would result in an acceleration of payments due. ALLETE has no significant restrictions on its ability to pay dividends from retained earnings or net income. As of December 31, 2021, ALLETE was in compliance with its financial covenants.

The entire disclosure for information about short-term and long-term debt arrangements, which includes amounts of borrowings under each line of credit, note payable, commercial paper issue, bonds indenture, debenture issue, own-share lending arrangements and any other contractual agreement to repay funds, and about the underlying arrangements, rationale for a classification as long-term, including repayment terms, interest rates, collateral provided, restrictions on use of assets and activities, whether or not in compliance with debt covenants, and other matters important to users of the financial statements, such as the effects of refinancing and noncompliance with debt covenants.

Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef
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Reference 3: http://www.xbrl.org/2003/role/disclosureRef
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Reference 4: http://www.xbrl.org/2003/role/disclosureRef
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Reference 7: http://www.xbrl.org/2003/role/disclosureRef
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Other Postretirement Benefits Plan [Member]

Pension and Other Postretirement Benefit Plans - Components of Net Periodic Expense (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2021

Dec. 31, 2020

Dec. 31, 2019

Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]

$ 3.6

$ 3.3

$ 3.9

Expected Return on Plan Assets

^[1]

4.4

5.0

7.3

^[1]

(9.9)

(9.7)

(10.5)

Amortization of Loss

^[1]

3.0

1.0

0.5

Amortization of Prior Service Cost

^[1]

(7.6)

(8.0)

(2.8)

Effect of Plan Curtailment

^[1]

0.0

(0.3)

(2.1)

Net Pension Cost

(6.5)

(8.7)

(3.7)

Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]

11.0

10.7

9.3

Expected Return on Plan Assets

^[2]

24.6

27.9

31.9

^[2]

(43.4)

(42.7)

(44.2)

Amortization of Loss

^[2]

18.8

12.8

7.5

Amortization of Prior Service Cost

^[2]

(0.2)

(0.1)

Net Pension Cost

$ 10.8

$ 8.5

$ 4.4

[1]	These components of net periodic postretirement health and life cost are included in the line item “Other” under Other Income (Expense) on the Consolidated Statement of Income.
[2]	These components of net periodic pension cost are included in the line item “Other” under Other Income (Expense) on the Consolidated Statement of Income.

Short-Term and Long-Term Debt - Financial Covenants (Details)	Dec. 31, 2021
Debt Instrument [Line Items]
Actual Indebtedness to Total Capitalization Ratio	0.41
Financial Covenants [Abstract]
Actual Indebtedness to Total Capitalization Ratio	0.41
Maximum [Member]
Debt Instrument [Line Items]
Allowed Indebtedness to Total Capitalization Ratio	0.65
Financial Covenants [Abstract]
Allowed Indebtedness to Total Capitalization Ratio	0.65

Regulatory Matters - Minnesota Solar Energy Standard (Details) $ in Millions	Dec. 31, 2021 USD ($) MW
Solar Generation
Regulatory Matters [Line Items]
Anticipated Generating Capacity to be Purchased (MW)	20
Estimated Investment Amount \| $	$ 40
MPUC [Member]
Regulatory Matters [Line Items]
Minnesota Solar Energy Standard - Overall Mandate Percentage	1.50%
MPUC [Member] \| Minimum [Member]
Regulatory Matters [Line Items]
Minnesota Solar Energy Standard - Overall Mandate Percentage	1.50%
Minnesota Solar Energy Standard - Small Scale Solar Mandate Percentage	10.00%
MPUC [Member] \| Maximum [Member]
Regulatory Matters [Line Items]
Minnesota Solar Energy Standard - Qualifying Capacity for Small Scale Solar Mandate (MW)	0.04

Pension and Other Postretirement Benefit Plans - Information for Pension Plans with an Accumulated Benefit Obligation in Excess of Plan Assets (Details) - Pension [Member] - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Projected Benefit Obligation	$ 911.7	$ 965.7
Accumulated Benefit Obligation	875.5	931.2
Fair Value of Plan Assets	$ 745.7	$ 759.4

Operations and Significant Accounting Policies - Revenue - Nature of Revenue Streams (Continued) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Capitalized Contract Cost, Amortization	$ 2.7	$ 2.6
Revenue, Performance Obligation, Description of Payment Terms	Payment terms and conditions vary across our businesses. Aside from taconite-producing Large Power Customers, payment terms generally require payment to be made within 15 to 30 days from the end of the period that the service has been rendered. In the case of its taconite-producing Large Power Customers, as permitted by the MPUC, Minnesota Power requires weekly payments for electric usage based on monthly energy usage estimates.
Long-term Contract with Customer [Member] \| Regulated Operations [Member] \| Industrial Customers [Member] \| Industrial [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Long-term Contract with Customer [Member] \| Regulated Operations [Member] \| Industrial Customers [Member] \| Industrial [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Amount	$ 50.0
Long-term Contract with Customer [Member] \| Regulated Operations [Member] \| Industrial Customers [Member] \| Industrial [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Amount	$ 50.0
Long-term Contract with Customer [Member] \| Regulated Operations [Member] \| Industrial Customers [Member] \| Industrial [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Amount	$ 50.0
Long-term Contract with Customer [Member] \| Regulated Operations [Member] \| Industrial Customers [Member] \| Industrial [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Amount	$ 50.0
Long-term Contract with Customer [Member] \| Regulated Operations [Member] \| Industrial Customers [Member] \| Industrial [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Amount	$ 15.0
Long-term Contract with Customer [Member] \| Regulated Operations [Member] \| Industrial Customers [Member] \| Industrial [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	3 years
Revenue, Remaining Performance Obligation, Amount	$ 30.0

Jointly-Owned Facilities and Assets (Tables)

12 Months Ended

Dec. 31, 2021

Jointly-Owned Facilities and Assets [Abstract]

Jointly-Owned Facilities and Assets [Table Text Block]

Minnesota Power’s investments in jointly-owned facilities and assets and the related ownership percentages are as follows:


Regulated Utility Plant	Plant in Service	Accumulated Depreciation	Construction Work in Progress	% Ownership
Millions
As of December 31, 2021
Boswell Unit 4	$682.7	$311.1	$30.1	80
Transmission Assets	101.0	18.5	—	9.3 - 14.7
Total	$783.7	$329.6	$30.1
As of December 31, 2020
Boswell Unit 4	$663.8	$288.8	$15.0	80
Transmission Assets	101.0	16.0	—	9.3 - 14.7
Total	$764.8	$304.8	$15.0

Equity Investments (Details)
$ in Millions

3 Months Ended

12 Months Ended

Jan. 31, 2022

USD ($)

Dec. 31, 2021

USD ($)

Sep. 30, 2021

USD ($)

Jun. 30, 2021

USD ($)

Mar. 31, 2021

USD ($)

Dec. 31, 2020

USD ($)

Sep. 30, 2020

USD ($)

Jun. 30, 2020

USD ($)

Mar. 31, 2020

USD ($)

Dec. 31, 2019

USD ($)

Sep. 30, 2019

USD ($)

Jun. 30, 2019

USD ($)

Mar. 31, 2019

USD ($)

Dec. 31, 2021

USD ($)

Dec. 31, 2020

USD ($)

Dec. 31, 2019

USD ($)

Equity Investment Beginning Balance

$ 301.2

17.6

$ 99.1

$ 37.9

Equity Investment Ending Balance

20.0

22.1

21.7

$ 318.0

$ 301.2

318.0

301.2

Assets [Abstract]

Total Current Assets

291.3

254.9

291.3

254.9

Total Assets

6,435.0

6,084.6

6,435.0

6,084.6

Liabilities and Equity [Abstract]

Liabilities, Current

543.4

459.6

543.4

459.6

Members' Equity

2,946.3

2,800.2

$ 2,335.6

2,946.3

2,800.2

2,335.6

Total Liabilities and Equity

6,435.0

6,084.6

6,435.0

6,084.6

399.0

$ 345.4

$ 335.6

339.2

320.4

$ 293.9

$ 243.2

$ 311.6

304.6

$ 288.3

$ 290.4

$ 357.2

1,419.2

1,169.1

1,240.5

Net Income

137.8

161.6

185.5

20.0

22.1

21.7

Approximate Refund for Reversal of FERC ROE Order

65.0

Approximate Refund for Reversale of FERC ROE Order, ALLETE's Proportionate Share

5.0

Approximate Reduction in Pretax Income for FERC Proposal to Limit Incentive adder, ALLETE's Proportionate Share

$ 1.0

FERC Proposed Reduction to Incentive Adder

0.50%

Expected Additional Investment in 2022

Ownership Percentage

8.00%

$ 6.0

Equity Investment Beginning Balance

149.0

$ 141.6

149.0

141.6

0.0

2.7

21.3

22.3

Amortization from the Remeasurement of Deferred Income Taxes for Equity Method Investments

(17.2)

(18.9)

1.4

1.3

Equity Investment Ending Balance

$ 154.5

149.0

$ 141.6

154.5

149.0

141.6

Authorized Return on Equity

$ 21.3

22.3

10.02%

Authorized Return on Equity, Including Incentive Adder

10.52%

ATC [Member] | Equity Method Investment, Nonconsolidated Investee or Group of Investees

Other Non-Current Liabilities

$ 21.3

22.3

21.7

Assets [Abstract]

Total Current Assets

$ 89.8

92.8

89.8

92.8

Assets, Noncurrent

5,628.1

5,400.5

5,628.1

5,400.5

Total Assets

5,717.9

5,493.3

5,717.9

5,493.3

Liabilities and Equity [Abstract]

Liabilities, Current

436.9

310.8

436.9

310.8

Long-Term Debt

2,513.0

2,512.2

2,513.0

2,512.2

422.0

378.2

422.0

378.2

Members' Equity

2,346.0

2,292.1

2,346.0

2,292.1

Total Liabilities and Equity

$ 5,717.9

5,493.3

5,717.9

5,493.3

754.8

758.1

744.4

Operating Expense

376.2

372.4

373.5

Other Expense

113.9

110.9

110.5

Net Income

264.7

274.8

260.4

ATC [Member] | Subsequent Event [Member]

$ 21.3

22.3

$ 21.7

$ 2.7

Ownership Percentage

49.00%

Equity Investment Beginning Balance

$ 152.2

17.6

^[1]

(1.3)

Equity Investment Ending Balance

(5.0)

$ 163.5

$ 152.2

163.5

$ 152.2

Tenaska [Member] | Nobles 2 PPA [Member] | Wind Turbine Generators [Member]

^[1]

$ (1.3)

Generating Capacity Counterparty Owned (MW) | MW

250

Contract Term (Years)

20 years

[1]	The Company also recorded net loss attributable to non-controlling interest of $6.6 million related to its investment in Nobles 2

Operations and Significant Accounting Policies - Revenue - Assets Recognized From the Costs to Obtain a Contract with a Customer (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2021

Dec. 31, 2020

Capitalized Contract Cost [Line Items]

Contract Asset - Noncurrent

^[1]

$ 23.3

$ 25.5

Capitalized Contract Cost, Amortization

$ 2.7

$ 2.6

[1]	Contract Assets include payments made to customers as an incentive to execute or extend service agreements. The contract payments are being amortized over the term of the respective agreements as a reduction to revenue.

Operations and Significant Accounting Policies - Concentration of Credit Risk (Details) - Customer Concentration Risk [Member] - Large Power Customers [Member] $ in Millions	12 Months Ended
	Dec. 31, 2021 USD ($) Customers	Dec. 31, 2020 USD ($) Customers	Dec. 31, 2019 Customers
Concentration Risk [Line Items]
Number of Large Power Customers	8	9	9
Receivables from Large Power Customers \| $	$ 7.8	$ 10.3
Number of entities	2
Largest Customer [Member] \| Consolidated Operating Revenue [Member]
Concentration Risk [Line Items]
Percent of Operating Revenue	28.00%	25.00%	12.00%
Largest Customer [Member] \| Consolidated Operating Revenue [Member] \| Regulated Operations [Member]
Concentration Risk [Line Items]
Percent of Operating Revenue	32.00%	29.00%	14.00%

Fair Value - Recurring Fair Value Measures (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2021

Dec. 31, 2020

Debt Securities, Available-for-sale, Maturity, Allocated and Single Maturity Date, within One Year, Fair Value

$ 1.0

Available-for-sale Securities, Debt Maturities, After One Year Through Three Years, Fair Value

2.3

Available-for-sale Securities, Debt Maturities, After Three Years Through Five Years, Fair Value

2.1

Available-for-sale Securities, Debt Maturities, After Five Years, Fair Value

0.8

Recurring Fair Value Measures [Member]

Available-for-sale – Corporate and Governmental Debt Securities

8.9

^[1]

$ 7.2

^[2]

6.2

^[1],[3]

10.4

^[2]

2.5

^[1]

5.5

^[2]

17.6

23.1

18.0

^[4]

21.0

^[5]

18.0

21.0

Fair Value Hierarchy Transfers, All Levels

(0.4)

2.1

0.0

Recurring Fair Value Measures [Member] | Level 1 [Member]

Available-for-sale – Corporate and Governmental Debt Securities

8.9

^[1]

7.2

^[2]

0.0

^[1],[3]

0.0

^[2]

2.5

^[1]

5.5

^[2]

11.4

12.7

0.0

^[4]

0.0

^[5]

0.0

Recurring Fair Value Measures [Member] | Level 2 [Member]

11.4

12.7

Available-for-sale – Corporate and Governmental Debt Securities

0.0

^[1]

0.0

^[2]

6.2

^[1],[3]

10.4

^[2]

0.0

^[1]

0.0

^[2]

6.2

10.4

18.0

^[4]

21.0

^[5]

18.0

21.0

Recurring Fair Value Measures [Member] | Level 3 [Member]

(11.8)

(10.6)

Available-for-sale – Corporate and Governmental Debt Securities

0.0

^[1]

0.0

^[2]

0.0

^[1],[3]

0.0

^[2]

0.0

^[1]

0.0

^[2]

0.0

0.0

^[4]

0.0

^[5]

0.0

Current Income Tax Expense [Abstract]

$ 0.0

[1]	Included in Other Non-Current Assets on the Consolidated Balance Sheet.
[2]	Included in Other Non-Current Assets on the Consolidated Balance Sheet.
[3]	As of December 31, 2021, the aggregate amount of available-for-sale corporate and governmental debt securities maturing in one year or less was $1.0 million, in one year to less than three years was $2.3 million, in three years to less than five years was $2.1 million and in five or more years was $0.8 million.
[4]	Included in Other Non-Current Liabilities on the Consolidated Balance Sheet.
[5]	Included in Other Non-Current Liabilities on the Consolidated Balance Sheet.

Income Tax Expense (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2021

Dec. 31, 2020

Dec. 31, 2019

Federal

^[1]

$ 0.0

State

^[1]

0.0

0.1

Total Current Income Tax Expense

^[1]

0.0

0.1

Deferred Income Tax Expense (Benefit) [Abstract]

Federal

^[2]

(37.2)

(48.8)

(27.8)

State

10.8

9.8

21.7

Investment Tax Credit Amortization

(0.5)

(0.6)

Total Deferred Income Tax Expense (Benefit)

(26.9)

(39.5)

(6.7)

Total Income Tax Expense (Benefit)

$ (26.9)

$ (39.5)

$ (6.6)

[1]	For the years ended December 31, 2021, 2020 and 2019, the federal and state current tax expense was minimal due to NOLs which resulted from the bonus depreciation and related tax attributes from large wind projects. Federal and state NOLs are being carried forward to offset current and future taxable income.
[2]	For the years ended December 31, 2021, 2020 and 2019, the federal tax benefit is primarily due to production tax credits.

Income Tax Expense - Deferred Income Tax Assets and Liabilities (Details) - USD ($)
$ in Millions

Dec. 31, 2021

Dec. 31, 2020

Deferred Income Tax Assets [Abstract]

Employee Benefits and Compensation

$ 44.5

$ 67.6

Property Related

54.8

61.4

NOL Carryforwards

67.5

60.7

Tax Credit Carryforwards

509.1

455.7

Power Sales Agreements

16.5

20.1

Regulatory Liabilities

101.5

107.7

Gross Deferred Income Tax Assets

0.0

22.4

793.9

795.6

Deferred Income Tax Asset Valuation Allowance

(69.0)

(69.9)

Total Deferred Income Tax Assets

724.9

725.7

Deferred Income Tax Liabilities [Abstract]

Property-Related

680.8

691.5

Regulatory Assets for Benefit Obligations

54.9

71.5

Unamortized Investment Tax Credits

30.5

31.1

Partnership Basis Differences

106.3

86.7

Regulatory Assets

30.0

32.6

Total Deferred Income Tax Liabilities

8.1

8.0

910.6

921.4

Net Deferred Income Taxes

^[1]

$ 185.7

$ 195.7

[1]	Recorded as a net long-term Deferred Income Tax liability on the Consolidated Balance Sheet.

Equity Investments Equity Investment in Nobles 2 (Details)
$ in Millions

12 Months Ended

Dec. 31, 2021

USD ($)

Dec. 31, 2020

USD ($)

Dec. 31, 2019

USD ($)

Equity Investments

$ 318.0

$ 301.2

17.6

99.1

$ 37.9

Net Loss Attributable to Non-Controlling Interest

20.0

22.1

21.7

(31.4)

(12.6)

(0.1)

Net Loss Attributable to Non-Controlling Interest

$ 6.6

Equity Method Investment, Ownership Percentage

49.00%

Equity Investments

$ 163.5

152.2

17.6

^[1]

(1.3)

$ (5.0)

Equity Method Investment, Ownership Percentage

8.00%

Equity Investments

$ 154.5

149.0

$ 141.6

Expected Additional Investment in 2022

0.0

2.7

6.0

21.3

22.3

Wind Turbine Generators [Member] | Tenaska [Member] | Nobles 2 PPA [Member]

$ (17.2)

$ (18.9)

Generating Capacity Counterparty Owned (MW) | MW

Contract Term (Years)

20 years

250

[1]	The Company also recorded net loss attributable to non-controlling interest of $6.6 million related to its investment in Nobles 2

Commitments, Guarantees and Contingencies - Other Matters (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
BNI Energy Reclamation Liability [Member]
Guarantor Obligations [Line Items]
Estimated Obligation	$ 70.7
BNI Energy Reclamation Liability [Member] \| Surety Bonds [Member]
Guarantor Obligations [Line Items]
Collateral	71.2
ALLETE Properties Development and Maintenance Obligations [Member]
Guarantor Obligations [Line Items]
Estimated Obligation	1.0
ALLETE Properties Development and Maintenance Obligations [Member] \| Surety Bonds and Letters of Credit [Member]
Guarantor Obligations [Line Items]
Collateral	2.0
Town Center District Capital Improvement Bonds [Member]
Guarantor Obligations [Line Items]
Bonds	$ 26.4
Bond Term (Years)	31 years
Ownership Percentage of Benefited Property	30.00%	48.00%
Annual Assessment	$ 1.8
Bond Interest Rate	6.00%
ALLETE, Inc. [Member] \| Letters of Credit [Member]
Guarantor Obligations [Line Items]
Standby Letters of Credit	$ 134.7
Regulated Operations [Member] \| Letters of Credit [Member]
Guarantor Obligations [Line Items]
Standby Letters of Credit	10.9
ALLETE Clean Energy [Member] \| Letters of Credit [Member]
Guarantor Obligations [Line Items]
Standby Letters of Credit	87.4
ALLETE South Wind [Member] \| Letters of Credit [Member]
Guarantor Obligations [Line Items]
Standby Letters of Credit	12.5
South Shore Energy \| Letters of Credit [Member]
Guarantor Obligations [Line Items]
Standby Letters of Credit	$ 23.9

Pension and Other Postretirement Benefit Plans - Reconciliation of Net Pension Amounts Recognized in Consolidated Balance Sheet (Details) - USD ($)
$ in Millions

Dec. 31, 2021

Dec. 31, 2020

Other Postretirement Benefits Plan [Member]

Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]

^[1]

$ 12.7

$ (23.0)

Accumulated Contributions in Excess of Net Periodic Benefit Cost (Prepaid Pension Asset)

(20.7)

(28.3)

20.2

13.1

Total Net Pension Amounts Recognized in Consolidated Balance Sheet

53.6

18.4

Pension Plan [Member]

Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]

(260.2)

(299.0)

Accumulated Contributions in Excess of Net Periodic Benefit Cost (Prepaid Pension Asset)

1.0

1.1

93.2

91.6

Total Net Pension Amounts Recognized in Consolidated Balance Sheet

(166.0)

(206.3)

Trust for Benefit of Employees [Member] | Other Postretirement Benefits Plan [Member]

Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]

Long-term Investments

$ 13.2

$ 20.4

[1]	Excludes gains, losses and contributions associated with irrevocable grantor trusts.

Consolidated Balance Sheet - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Current Assets [Abstract]
Cash and Cash Equivalents	$ 45.1	$ 44.3
Accounts Receivable (Less Allowance of $1.8 and $2.5)	123.7	111.9
Inventories – Net	97.7	74.2
Prepayments and Other	24.8	24.5
Total Current Assets	291.3	254.9
Property, Plant and Equipment – Net	5,100.2	4,840.8
Regulatory Assets	511.8	480.9
Equity Investments	318.0	301.2
Other Non-Current Assets	213.7	206.8
Total Assets	6,435.0	6,084.6
Current Liabilities [Abstract]
Accounts Payable	111.0	110.0
Accrued Taxes	65.1	59.4
Accrued Interest	20.1	19.8
Long-Term Debt Due Within One Year	214.2	203.7
Other	133.0	66.7
Total Current Liabilities	543.4	459.6
Long-Term Debt	1,763.2	1,593.2
Deferred Income Taxes	185.7	195.7
Regulatory Liabilities	536.1	524.8
Defined Benefit Pension and Other Postretirement Benefit Plans	179.5	225.8
Other Non-Current Liabilities	280.8	285.3
Total Liabilities	3,488.7	3,284.4
Commitments, Guarantees and Contingencies (Note 8)
ALLETE Equity [Abstract]
Common Stock Without Par Value, 80.0 Shares Authorized, 53.2 and 52.1 Shares Issued and Outstanding	1,536.7	1,460.9
Accumulated Other Comprehensive Loss	(23.8)	(31.1)
Retained Earnings	900.2	864.8
Total ALLETE Equity	2,413.1	2,294.6
Non-Controlling Interest in Subsidiaries	533.2	505.6
Total Equity	2,946.3	2,800.2
Total Liabilities and Equity	$ 6,435.0	$ 6,084.6

Operations and Significant Accounting Policies - Revenue - Nature of Revenue Streams (Details)	12 Months Ended
	Dec. 31, 2021 Customers MW	Dec. 31, 2020 Customers	Dec. 31, 2019 Customers
Disaggregation of Revenue [Line Items]
Revenue, Performance Obligation, Description of Payment Terms	Payment terms and conditions vary across our businesses. Aside from taconite-producing Large Power Customers, payment terms generally require payment to be made within 15 to 30 days from the end of the period that the service has been rendered. In the case of its taconite-producing Large Power Customers, as permitted by the MPUC, Minnesota Power requires weekly payments for electric usage based on monthly energy usage estimates.
Regulated Operations [Member] \| Alternative Programs [Member]
Disaggregation of Revenue [Line Items]
Revenue Collection Period Following the Annual Period it is Recognized	24 months
Regulated Operations [Member] \| Retail Electric Service [Member] \| Industrial [Member] \| Industrial Customers [Member]
Disaggregation of Revenue [Line Items]
Percentage of Total Regulated Utility kWh Sales	47.00%
Long-term Contract with Customer [Member] \| Regulated Operations [Member] \| Wholesale Electric Service [Member] \| Municipal [Member] \| Municipal Customers [Member]
Disaggregation of Revenue [Line Items]
Number of Customers	15
Long-term Contract with Customer [Member] \| Regulated Operations [Member] \| Retail Electric Service [Member] \| Industrial [Member] \| Industrial Customers [Member]
Disaggregation of Revenue [Line Items]
Length of Notice Required to Terminate Contract	4 years
Large Power Customer Contracts	8
Contract Serving Requirement \| MW	10
Long-term Contract with Customer [Member] \| Regulated Operations [Member] \| Retail Electric Service [Member] \| Municipal Customers [Member] \| Municipal [Member]
Disaggregation of Revenue [Line Items]
Length of Notice Required to Terminate Contract	3 years
Long-term Contract with Customer [Member] \| Regulated Operations [Member] \| Sale of Energy under PSA [Member] \| Other Power Suppliers [Member] \| Other Power Supplier Customers [Member]
Disaggregation of Revenue [Line Items]
Number of Customers	1
Customer Concentration Risk [Member] \| Large Power Customers [Member]
Disaggregation of Revenue [Line Items]
Number of Customers	8	9	9
Customer Concentration Risk [Member] \| Consolidated Operating Revenue [Member] \| Large Power Customers [Member] \| Largest Customer [Member]
Disaggregation of Revenue [Line Items]
Concentration Risk, Percentage	28.00%	25.00%	12.00%
Customer Concentration Risk [Member] \| Consolidated Operating Revenue [Member] \| Large Power Customers [Member] \| Regulated Operations [Member] \| Largest Customer [Member]
Disaggregation of Revenue [Line Items]
Concentration Risk, Percentage	32.00%	29.00%	14.00%

Pension and Other Postretirement Benefit Plans - Contributions (Details) - USD ($) shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
ESOP Compensation Expense	$ 11.5	$ 11.2	$ 10.8
Common Stock [Member]
Defined Benefit Plan Disclosure [Line Items]
Employer Contributions to Defined Benefit Pension Plans - Common Stock Shares			0
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Employer Contributions to Defined Benefit Pension Plans - Cash	$ 10.3	10.7	$ 10.4
Defined Benefit Plan - Amendments	The non-union defined benefit pension plan was frozen in 2018, and does not allow further crediting of service or earnings to the plan. Further, it is closed to new participants. The Minnesota Power union defined benefit pension plan is also closed to new participants, and the SWL&P union defined benefit pension plan was closed to new participants effective February 1, 2022.
Expected Employer Contributions in 2022	$ 0.0
Postretirement Health and Life [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected Employer Contributions in 2022	0.0
Postretirement Health and Life [Member] \| VEBA [Member]
Defined Benefit Plan Disclosure [Line Items]
Employer Contributions to Other Postretirement Benefit Plans	0.0	0.0	0.0
Postretirement Health and Life [Member] \| Irrevocable Grantor Trust [Member]
Defined Benefit Plan Disclosure [Line Items]
Employer Contributions to Other Postretirement Benefit Plans	$ 0.0	$ 0.0	$ 0.0

Pension and Other Postretirement Benefit Plans (Tables)

12 Months Ended

Dec. 31, 2021

Estimated Future Benefit Payments [Table Text Block]


Estimated Future Benefit Payments	Pension	Postretirement Health and Life
Millions
2022	$54.6	$8.4
2023	$54.4	$8.4
2024	$54.4	$8.4
2025	$53.8	$8.2
2026	$53.1	$8.1
Years 2027 – 2031	$257.2	$41.6

Weighted Average Assumptions Used to Determine Benefit Obligation and Net Periodic Benefit Costs [Table Text Block]


Weighted Average Assumptions Used to Determine Benefit Obligation
As of December 31	2021	2020
Discount Rate
Pension	3.05%	2.62%
Postretirement Health and Life	3.09%	2.70%
Rate of Compensation Increase	3.58%	3.61%
Health Care Trend Rates
Trend Rate	5.66%	5.81%
Ultimate Trend Rate	4.50%	4.50%
Year Ultimate Trend Rate Effective	2038	2038


Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Year Ended December 31	2021	2020	2019
Discount Rate
Pension	2.87%	3.52%	4.67%
Postretirement Health and Life	2.70%	3.45%	4.47%
Expected Long-Term Return on Plan Assets (a)
Pension	6.50%	6.75%	7.25%
Postretirement Health and Life	5.85%	6.08%	6.51%
Rate of Compensation Increase	3.62%	4.06%	4.04%

(a)The expected long-term rates of return used to determine net periodic benefit expense for 2022 have been reduced to 6.00 percent for pension expense and 4.80 percent to 6.00 percent for postretirement health and life expense.

Plan Asset Actual and Target Allocations [Table Text Block]


Actual Plan Asset Allocations	Pension		Postretirement Health and Life (a)
	2021	2020	2021	2020
Equity Securities	49%	36%	70%	67%
Fixed Income Securities	48%	61%	29%	32%
Private Equity	—	1	1%	1%
Real Estate	3%	2%	—	—
	100%	100%	100%	100%

(a)Includes VEBAs and irrevocable grantor trusts.

Following are the current targeted allocations as of December 31, 2021:


Plan Asset Target Allocations	Pension		Postretirement Health and Life (a)
Equity Securities	49	%	60	%
Fixed Income Securities	49	%	37	%
Private Equity	1	%	—
Real Estate	1	%	3	%
	100	%	100	%

(a)Includes VEBAs and irrevocable grantor trusts.

Obligation and Funded Status [Table Text Block]


Pension Obligation and Funded Status
As of December 31	2021	2020
Millions
Accumulated Benefit Obligation	$875.5	$931.2
Change in Benefit Obligation
Obligation, Beginning of Year	$965.7	$854.0
Service Cost	11.0	10.7
Interest Cost	24.6	27.9

Plan Curtailments	(1.4)	—
Actuarial (Gain) Loss (a)	(39.0)	118.7
Benefits Paid	(56.5)	(54.4)
Participant Contributions	7.3	8.8
Obligation, End of Year	$911.7	$965.7
Change in Plan Assets
Fair Value, Beginning of Year	$759.4	$699.6
Actual Return on Plan Assets	23.1	93.0
Employer Contribution (b)	19.7	21.2
Benefits Paid	(56.5)	(54.4)
Fair Value, End of Year	$745.7	$759.4
Funded Status, End of Year	$(166.0)	$(206.3)

Net Pension Amounts Recognized in Consolidated Balance Sheet Consist of:
Current Liabilities	$(2.1)	$(2.2)
Non-Current Liabilities	$(163.9)	$(204.1)

(a) Actuarial (gain) loss was primarily the result of increases in discount rates in 2021 compared to decreases in 2020.

(b) Includes Participant Contributions noted above.

Amounts Recognized in Consolidated Balance Sheet [Table Text Block]


Reconciliation of Net Pension Amounts Recognized in Consolidated Balance Sheet
As of December 31	2021	2020
Millions
Net Loss	$(260.2)	$(299.0)
Prior Service Credit	1.0	1.1
Accumulated Contributions in Excess of Net Periodic Benefit Cost (Prepaid Pension Asset)	93.2	91.6
Total Net Pension Amounts Recognized in Consolidated Balance Sheet	$(166.0)	$(206.3)

Components of Net Periodic Cost [Table Text Block]


Components of Net Periodic Pension Cost
Year Ended December 31	2021	2020	2019
Millions
Service Cost	$11.0	$10.7	$9.3
Non-Service Cost Components (a)
Interest Cost	24.6	27.9	31.9
Expected Return on Plan Assets	(43.4)	(42.7)	(44.2)
Amortization of Loss	18.8	12.8	7.5
Amortization of Prior Service Credit	(0.2)	(0.2)	(0.1)
Net Pension Cost	$10.8	$8.5	$4.4

(a)These components of net periodic pension cost are included in the line item “Other” under Other Income (Expense) on the Consolidated Statement of Income.

Information for Pension Plans with an Accumulated Benefit Obligation in Excess of Plan Assets [Table Text Block]


Information for Pension Plans with an Accumulated Benefit Obligation in Excess of Plan Assets
As of December 31	2021	2020
Millions
Projected Benefit Obligation	$911.7	$965.7
Accumulated Benefit Obligation	$875.5	$931.2
Fair Value of Plan Assets	$745.7	$759.4

Other Changes in Plan Assets and Benefit Obligations Recognized in Other Comprehensive Income and Regulatory Assets or Liabilities [Table Text Block]


Other Changes in Pension Plan Assets and Benefit Obligations Recognized in Other Comprehensive Income and Regulatory Assets or Liabilities
Year Ended December 31	2021	2020
Millions
Net (Gain) Loss	$(20.1)	$68.4
Amortization of Prior Service Credit	0.2	0.2

Amortization of Loss	(18.8)	(12.8)
Total Recognized in Other Comprehensive Income and Regulatory Assets or Liabilities	$(38.7)	$55.8

Recurring Fair Value Measures [Table Text Block]


	Fair Value as of December 31, 2021
Recurring Fair Value Measures	Level 1	Level 2	Level 3	Total
Millions
Assets:
Equity Securities:
U.S. Large-cap (a)	—	$113.8	—	$113.8
U.S. Mid-cap Growth (a)	—	47.6	—	47.6
U.S. Small-cap (a)	—	46.2	—	46.2

International	—	158.2	—	158.2



Fixed Income Securities (a)	—	346.1	—	346.1
Cash and Cash Equivalents	$12.2	—	—	12.2

Private Equity Funds	—	—	—	—
Real Estate	—	—	$21.6	21.6
Total Fair Value of Assets	$12.2	$711.9	$21.6	$745.7

(a)The underlying investments consist of actively-managed funds managed to achieve the returns of certain U.S. equity and fixed income securities indexes.


	Fair Value as of December 31, 2020
Recurring Fair Value Measures	Level 1	Level 2	Level 3	Total
Millions
Assets:
Equity Securities:
U.S. Large-cap (a)	—	$91.7	—	$91.7
U.S. Mid-cap Growth (a)	—	40.0	—	40.0
U.S. Small-cap (a)	—	40.7	—	40.7

International	—	97.1	—	97.1



Fixed Income Securities (a)	—	461.7	—	461.7
Cash and Cash Equivalents	$3.2	—	—	3.2

Private Equity Funds	—	—	$7.0	7.0
Real Estate	—	—	18.0	18.0
Total Fair Value of Assets	$3.2	$731.2	$25.0	$759.4

(a)The underlying investments consist of actively-managed funds managed to achieve the returns of certain U.S. equity and fixed income securities indexes.

Recurring Fair Value Measures - Activity in Level 3 [Table Text Block]


Recurring Fair Value Measures
Activity in Level 3	Private Equity Funds	Real Estate
Millions
Balance as of December 31, 2020	$7.0	$18.0
Actual Return on Plan Assets	(3.5)	3.6
Purchases, Sales, and Settlements – Net	(3.5)	—
Balance as of December 31, 2021	—	$21.6


Recurring Fair Value Measures
Activity in Level 3	Private Equity Funds	Real Estate
Millions
Balance as of December 31, 2019	$8.0	$18.0
Actual Return on Plan Assets	0.1	—
Purchases, Sales, and Settlements – Net	(1.1)	—
Balance as of December 31, 2020	$7.0	$18.0

Postretirement Health and Life [Member]

Obligation and Funded Status [Table Text Block]


Postretirement Health and Life Obligation and Funded Status
As of December 31	2021	2020
Millions
Change in Benefit Obligation
Obligation, Beginning of Year	$167.6	$149.8
Service Cost	3.6	3.3
Interest Cost	4.4	5.0
Actuarial (Gain) Loss (a)	(19.7)	19.2
Benefits Paid	(10.6)	(12.6)
Participant Contributions	2.9	3.2

Plan Curtailments	—	(0.3)

Obligation, End of Year	$148.2	$167.6
Change in Plan Assets
Fair Value, Beginning of Year	$186.0	$173.7
Actual Return on Plan Assets	22.8	20.9
Employer Contribution	0.7	0.8
Participant Contributions	2.9	3.2
Benefits Paid	(10.6)	(12.6)
Fair Value, End of Year	$201.8	$186.0
Funded Status, End of Year	$53.6	$18.4

Net Postretirement Health and Life Amounts Recognized in Consolidated Balance Sheet Consist of:
Non-Current Assets	$64.8	$34.2
Current Liabilities	$(1.4)	$(0.6)
Non-Current Liabilities	$(9.8)	$(15.2)

(a)Actuarial (gain) loss was primarily the result of increases in discount rates in 2021 compared to decreases in 2020.

Amounts Recognized in Consolidated Balance Sheet [Table Text Block]


Reconciliation of Net Postretirement Health and Life Amounts Recognized in Consolidated Balance Sheet
As of December 31	2021	2020
Millions
Net Gain (Loss) (a)	$12.7	$(23.0)
Prior Service Credit	20.7	28.3
Accumulated Net Periodic Benefit Cost in Excess of Contributions (a)	20.2	13.1
Total Net Postretirement Health and Life Amounts Recognized in Consolidated Balance Sheet	$53.6	$18.4

(a)Excludes gains, losses and contributions associated with irrevocable grantor trusts.

Components of Net Periodic Cost [Table Text Block]


Components of Net Periodic Postretirement Health and Life Cost
Year Ended December 31	2021	2020	2019
Millions
Service Cost	$3.6	$3.3	$3.9
Non-Service Cost Components (a)
Interest Cost	4.4	5.0	7.3
Expected Return on Plan Assets	(9.9)	(9.7)	(10.5)
Amortization of Loss	3.0	1.0	0.5
Amortization of Prior Service Credit	(7.6)	(8.0)	(2.8)

Effect of Plan Curtailment	—	(0.3)	(2.1)
Net Postretirement Health and Life Credit	$(6.5)	$(8.7)	$(3.7)

(a)These components of net periodic postretirement health and life cost are included in the line item “Other” under Other Income (Expense) on the Consolidated Statement of Income.

Other Changes in Plan Assets and Benefit Obligations Recognized in Other Comprehensive Income and Regulatory Assets or Liabilities [Table Text Block]


Other Changes in Postretirement Benefit Plan Assets and Benefit Obligations Recognized in Other Comprehensive Income and Regulatory Assets or Liabilities
Year Ended December 31	2021	2020
Millions
Net (Gain) Loss	$(32.7)	$8.1

Amortization of Prior Service Credit	7.6	8.0

Amortization of Loss	(3.0)	(1.0)

Total Recognized in Other Comprehensive Income and Regulatory Assets or Liabilities	$(28.1)	$15.1

Unrecognized Postretirement Health and Life Costs [Table Text Block]

The postretirement health and life costs that are reported as a component within the Consolidated Balance Sheet, reflected in regulatory long-term assets or liabilities and accumulated other comprehensive income, consist of the following:


Unrecognized Postretirement Health and Life Costs
As of December 31	2021	2020
Millions
Net (Gain) Loss	$(12.7)	$23.0
Prior Service Credit	(20.7)	(28.3)

Total Unrecognized Postretirement Health and Life Cost	$(33.4)	$(5.3)

Recurring Fair Value Measures [Table Text Block]


	Fair Value as of December 31, 2021
Recurring Fair Value Measures	Level 1	Level 2	Level 3	Total
Millions
Assets:
Equity Securities: (a)
U.S. Large-cap	$40.1	—	—	$40.1
U.S. Mid-cap Growth	37.3	—	—	37.3
U.S. Small-cap	19.3	—	—	19.3
International	43.7	—	—	43.7
Fixed Income Securities:
Mutual Funds	56.7	—	—	56.7
Debt Securities	—	$1.8	—	1.8
Cash and Cash Equivalents	0.9	—	—	0.9

Private Equity Funds	—	—	$2.0	2.0
Total Fair Value of Assets	$198.0	$1.8	$2.0	$201.8

(a)The underlying investments consist of mutual funds (Level 1).


	Fair Value as of December 31, 2020
Recurring Fair Value Measures	Level 1	Level 2	Level 3	Total
Millions
Assets:
Equity Securities: (a)
U.S. Large-cap	$34.2	—	—	$34.2
U.S. Mid-cap Growth	31.4	—	—	31.4
U.S. Small-cap	16.6	—	—	16.6
International	41.5	—	—	41.5
Fixed Income Securities:
Mutual Funds	57.3	—	—	57.3
Debt Securities	—	$2.2	—	2.2
Cash and Cash Equivalents	1.1	—	—	1.1

Private Equity Funds	—	—	$1.7	1.7
Total Fair Value of Assets	$182.1	$2.2	$1.7	$186.0

(a)The underlying investments consist of mutual funds (Level 1).

Recurring Fair Value Measures - Activity in Level 3 [Table Text Block]


Recurring Fair Value Measures
Activity in Level 3			Private Equity Funds
Millions
Balance as of December 31, 2020			$1.7
Actual Return on Plan Assets			0.8
Purchases, Sales, and Settlements – Net			(0.5)
Balance as of December 31, 2021			$2.0


Recurring Fair Value Measures
Activity in Level 3			Private Equity Funds
Millions
Balance as of December 31, 2019			$1.7
Actual Return on Plan Assets			—
Purchases, Sales, and Settlements – Net			—
Balance as of December 31, 2020			$1.7

Schedule II

12 Months Ended

Dec. 31, 2021

SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract]

Schedule II [Text Block]

Schedule II

ALLETE

Valuation and Qualifying Accounts and Reserves


	Balance at Beginning of Period	Additions		Deductions from Reserves (a)	Balance at End of Period
		Charged to Income	Other Charges
Millions
Reserve Deducted from Related Assets
Reserve For Uncollectible Accounts
2019 Trade Accounts Receivable	$1.7	$(0.1)	—	$0.7	$0.9
Finance Receivables – Long-Term	—	—	—	—	—
2020 Trade Accounts Receivable	$0.9	$2.7	—	$1.1	$2.5
Finance Receivables – Long-Term	—	—	—	—	—
2021 Trade Accounts Receivable	$2.5	$1.2	—	$1.9	$1.8
Finance Receivables – Long-Term	—	—	—	—	—
Deferred Asset Valuation Allowance
2019 Deferred Tax Assets	$66.5	$3.5	—	—	$70.0
2020 Deferred Tax Assets	$70.0	$(0.1)	—	—	$69.9
2021 Deferred Tax Assets	$69.9	$(0.9)	—	—	$69.0

(a) Includes uncollectible accounts written-off.

Regulatory Matters - Electric Rates (Details) $ in Millions					3 Months Ended	4 Months Ended	8 Months Ended	12 Months Ended			18 Months Ended
Regulatory Matters - Electric Rates (Details) $ in Millions	Jan. 13, 2022 USD ($)	Nov. 01, 2021 USD ($)	Nov. 01, 2019 USD ($)	Dec. 20, 2018	Jun. 30, 2020 USD ($)	Apr. 30, 2020 USD ($)	Dec. 31, 2020	Dec. 31, 2021 USD ($) Customers Years	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)	Dec. 31, 2019 USD ($)
Cost Recovery Riders [Member]
Regulatory Matters [Line Items]
Alternative Revenue Program, Required Collection Period								2 years
MPUC [Member] \| Fuel Adjustment Clause Filing [Member]
Regulatory Matters [Line Items]
Forced Outage Costs											$ 8.0
Administrative Law Judge Recommended Refund								$ 5.0
MPUC [Member] \| Fuel Adjustment Clause Filing [Member] \| Subsequent Event [Member]
Regulatory Matters [Line Items]
Commission Approved Refund	$ 5.0
MPUC [Member] \| Minnesota Power Land Sales
Regulatory Matters [Line Items]
Estimated Market Value - Reservoir Land to be Sold								100.0
PSCW [Member] \| 2018 Wisconsin General Rate Case [Member] \| Retail Customers [Member]
Regulatory Matters [Line Items]
Approved Return on Common Equity				10.40%
Approved Equity Ratio				55.00%
Electric Rates [Member] \| MPUC [Member] \| Minnesota Cost Recovery Riders [Member] \| Retail Customers [Member]
Regulatory Matters [Line Items]
Revenue from Cost Recovery Riders								$ 38.9	$ 29.9	$ 31.8
Electric Rates [Member] \| MPUC [Member] \| 2020 Minnesota General Rate Review [Member] \| Retail Customers [Member]
Regulatory Matters [Line Items]
Requested Average Rate Increase			10.60%
Requested Return on Equity			10.05%
Requested Equity Ratio			53.81%
Annual Additional Revenue Generated from Requested Final Rate Increase			$ 66.0
Public Utilities, Interim Rate Increase (Decrease), Amount						$ 36.1
Proposed Ongoing Customer Rate Increase							4.10%
Public Utilities, Interim Rate Increase (Decrease), Percentage						5.80%
Public Utilities Reserve for Interim Rates (Recorded During Period)					$ 11.7
Electric Rates [Member] \| MPUC [Member] \| 2022 Minnesota General Rate Review \| Retail Customers [Member]
Regulatory Matters [Line Items]
Requested Average Rate Increase		18.00%
Requested Return on Equity		10.25%
Requested Equity Ratio		53.81%
Annual Additional Revenue Generated from Requested Final Rate Increase		$ 108.0
Public Utilities, Interim Rate Increase (Decrease), Amount		80.0
Electric Rates [Member] \| MPUC [Member] \| 2022 Minnesota General Rate Review \| Residential [Member]
Regulatory Matters [Line Items]
Deferred Interim Rates		$ 8.0
Electric Rates [Member] \| FERC [Member] \| FERC-Approved Wholesale Rates [Member] \| Municipal Customers [Member]
Regulatory Matters [Line Items]
Number of Customers \| Customers								15
Notice Required to Terminate (Years) \| Years								3
Electric Rates [Member] \| FERC [Member] \| FERC-Approved Wholesale Rates [Member] \| Municipal Customers [Member] \| Wholesale Electric Contract (Cost-Based Formula Methodology for Entire Term) [Member]
Regulatory Matters [Line Items]
Number of Customers \| Customers								2
Electric Rates [Member] \| FERC [Member] \| FERC-Approved Wholesale Rates [Member] \| Municipal Customers [Member] \| Wholesale Electric Contracts (expire December 2024) [Member]
Regulatory Matters [Line Items]
Number of Customers \| Customers								1
Electric Rates [Member] \| FERC [Member] \| FERC-Approved Wholesale Rates [Member] \| Municipal Customers [Member] \| Wholesale Electric Contracts (Through 2029)
Regulatory Matters [Line Items]
Number of Customers \| Customers								13

Pension and Other Postretirement Benefit Plans - Plan Asset Allocations (Details) - shares
shares in Millions

Dec. 31, 2021

Dec. 31, 2020

Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]

ALLETE Common Stock Included in Pension Plan Equity Securities (Shares)

100.00%

0.0

Pension [Member] | Equity Securities [Member]

100.00%

Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]

49.00%

36.00%

Pension [Member] | Fixed Income [Member]

49.00%

Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]

48.00%

61.00%

Pension [Member] | Private Equity [Member]

49.00%

Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]

0.00%

1.00%

Pension [Member] | Real Estate [Member]

1.00%

Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]

3.00%

2.00%

Postretirement Health and Life [Member]

1.00%

Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]

^[1]

100.00%

Postretirement Health and Life [Member] | Equity Securities [Member]

^[2]

100.00%

Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]

^[1]

70.00%

67.00%

Postretirement Health and Life [Member] | Fixed Income [Member]

^[2]

60.00%

Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]

^[1]

29.00%

32.00%

Postretirement Health and Life [Member] | Private Equity [Member]

^[2]

37.00%

Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]

^[1]

1.00%

Postretirement Health and Life [Member] | Real Estate [Member]

^[2]

0.00%

Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]

^[1]

0.00%

Schedule of Regulatory Assets and Liabilities

^[2]

3.00%

[1]	Includes VEBAs and irrevocable grantor trusts.
[2]	Includes VEBAs and irrevocable grantor trusts.

Regulatory Matters (Tables)

12 Months Ended

Dec. 31, 2021

Regulated Operations [Abstract]


Regulatory Assets and Liabilities
As of December 31	2021	2020
Millions



Non-Current Regulatory Assets

Defined Benefit Pension and Other Postretirement Benefit Plans (a)	$226.4	$259.7

Income Taxes (b)	104.7	113.7
Cost Recovery Riders (c)	63.2	54.0
Fuel Adjustment Clause (d)	56.4	—
Asset Retirement Obligations (e)	33.1	31.6
Manufactured Gas Plant (f)	17.0	8.8
PPACA Income Tax Deferral	4.3	4.5
Conservation Improvement Program (g)	2.4	—
Boswell Units 1 and 2 Net Plant and Equipment (h)	—	5.0
Other	4.3	3.6
Total Non-Current Regulatory Assets	$511.8	$480.9


Current Regulatory Liabilities (i)

Fuel Adjustment Clause (d)	$5.0	$3.7

Transmission Formula Rates	3.1	2.9
Other	0.5	1.0
Total Current Regulatory Liabilities	8.6	7.6
Non-Current Regulatory Liabilities

Income Taxes (b)	353.4	375.3
Wholesale and Retail Contra AFUDC (j)	83.7	86.6

Plant Removal Obligations (k)	52.6	41.2
Defined Benefit Pension and Other Postretirement Benefit Plans (a)	28.1	4.4
North Dakota Investment Tax Credits (l)	12.2	12.0
Boswell Units 1 and 2 Net Plant and Equipment (h)	0.4	—
Conservation Improvement Program (g)	—	1.5


Other	5.7	3.8
Total Non-Current Regulatory Liabilities	536.1	524.8
Total Regulatory Liabilities	$544.7	$532.4

(a)Defined benefit pension and other postretirement items included in our Regulated Operations, which are otherwise required to be recognized in accumulated other comprehensive income as actuarial gains and losses as well as prior service costs and credits, are recognized as regulatory assets or regulatory liabilities on the Consolidated Balance Sheet. The asset or liability will decrease as the deferred items are amortized and recognized as components of net periodic benefit cost. (See Note 11. Pension and Other Postretirement Benefit Plans.)

(b)These costs represent the difference between deferred income taxes recognized for financial reporting purposes and amounts previously billed to our customers. The balances will primarily decrease over the remaining life of the related temporary differences.

(c)The cost recovery rider regulatory assets and liabilities are revenue not yet collected from our customers and cash collections from our customers in excess of the revenue recognized, respectively, primarily due to capital expenditures related to Bison, the Boswell Unit 4 environmental upgrade and the GNTL as well as differences between production tax credits recognized and those assumed in Minnesota Power’s base rates. The cost recovery rider regulatory assets as of December 31, 2021, will be recovered within the next two years.

(d)Fuel adjustment clause regulatory asset and liability represent the amount expected to be recovered from or refunded to customers for the under- or over-collection of fuel adjustment clause recoveries. (See Fuel Adjustment Clause.)

(e)Asset retirement obligations will accrete and be amortized over the lives of the related property with asset retirement obligations.

(f)The manufactured gas plant regulatory asset represents costs of remediation for a former manufactured gas plant site located in Superior, Wisconsin, and formerly operated by SWL&P. We expect recovery of these remediation costs to be allowed by the PSCW in rates over time.

(g)The conservation improvement program regulatory liability represents CIP expenditures, any financial incentive earned for cost-effective program achievements and a carrying charge deferred for future refund over the next year following MPUC approval.

(h)In 2018, Minnesota Power retired Boswell Units 1 and 2 and reclassified the remaining net book value from property, plant and equipment to a regulatory asset on the Consolidated Balance Sheet. The remaining net book value is currently included in Minnesota Power’s rate base and Minnesota Power is earning a return on the outstanding balance.

(i)Current regulatory liabilities are presented within Other Current Liabilities on the Consolidated Balance Sheet.

(j)Wholesale and retail contra AFUDC represents amortization to offset AFUDC Equity and Debt recorded during the construction period of our cost recovery rider projects prior to placing the projects in service. The regulatory liability will decrease over the remaining depreciable life of the related asset.

(k)Non-legal plant removal obligations included in retail customer rates that have not yet been incurred.

(l)North Dakota investment tax credits expected to be realized from Bison that will be credited to Minnesota Power’s retail customers through future renewable cost recovery rider filings as the tax credits are utilized.

Commitments, Guarantees and Contingencies Minimum Payments for Certain Long-Term Commitments (Details)
$ in Millions

Dec. 31, 2021

USD ($)

Capital Purchase Obligations [Member]

Minimum Annual Payments for Certain Long-Term Commitments [Line Items]

$ 50.7

0.1

0.0

0.0

0.0

Minimum Annual Payments for Certain Long-Term Commitments [Line Items]

0.0

Easements [Member]

8.2

^[1]

8.4

^[1]

8.4

^[1]

8.8

^[1]

9.2

^[1]

Minimum Annual Payments for Certain Long-Term Commitments [Line Items]

239.7

^[1]

PPAs [Member]

141.1

^[2]

140.7

^[2]

133.5

^[2]

131.4

^[2]

138.3

^[2]

Long-Term Service Agreements [Member]

1,060.6

^[2]

Minimum Annual Payments for Certain Long-Term Commitments [Line Items]

58.9

^[3]

22.5

^[3]

23.1

^[3]

0.0

^[3]

0.0

^[3]

Reconciliation of Taxes from Federal Statutory Rate to Total Income Tax Expense [Abstract]

$ 0.0

^[3]

[1]	Easement obligations represent the minimum payments for our land easement agreements at our wind energy facilities.
[2]	Does not include the agreement with Manitoba Hydro expiring in 2022, as this contract is for surplus energy only; or the Oliver Wind I, Oliver Wind II or Nobles 2 PPAs, as Minnesota Power only pays for energy as it is delivered. (See Power Purchase Agreements.)
[3]	Consists of long-term service agreements for wind energy facilities and minimum purchase commitments under coal and rail contracts.

Employee Stock and Incentive Plans - Share-Based Compensation Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Share-Based Compensation Expense [Line Items]
Share-Based Compensation Expense	$ 3.0	$ 3.1	$ 3.1
Income Tax Benefit	0.9	0.9	0.9
Capitalized Share-Based Compensation Costs	$ 0.0	0.0	0.0
Performance Shares [Member]
Share-Based Compensation Expense [Line Items]
Performance Period (Years)	3 years
Share-Based Compensation Expense	$ 2.0	2.2	2.3
Unrecognized Compensation Cost	$ 1.8
Weighted-Average Period for Recognition (Years/Months)	1 year 8 months 12 days
Restricted Stock Units [Member]
Share-Based Compensation Expense [Line Items]
Performance Period (Years)	3 years
Share-Based Compensation Expense	$ 1.0	$ 0.9	$ 0.8
Unrecognized Compensation Cost	$ 0.9
Weighted-Average Period for Recognition (Years/Months)	1 year 7 months 6 days

Operations and Significant Accounting Policies - Leases (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Lessee, Lease, Description [Line Items]
Lessee, Operating Lease, Residual Value Guarantee, Description	Our largest operating lease is for the dragline at BNI Energy which includes a termination payment at the end of the lease term if we do not exercise our purchase option.
Operating Lease, Right-of-Use Asset	$ 16.4	$ 22.4
Operating Lease, Cost	6.7	8.3
Operating Lease, Payments	6.7	$ 8.3
Operating Lease Liabilities, Current	4.8
Operating Lease Liabilities, Non-Current	11.6
Operating Lease, Liability	16.4
Residual Value of Leased Asset	$ 3.0
Operating Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other	Other
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Other Non-Current Liabilities	Other Non-Current Liabilities
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Other Non-Current Assets	Other Non-Current Assets
Other Liabilities
Lessee, Lease, Description [Line Items]
Operating Lease, Liability	$ 16.4	$ 22.4
Other Noncurrent Liabilities
Lessee, Lease, Description [Line Items]
Operating Lease Liabilities, Non-Current	11.6	16.5
Other Current Liabilities
Lessee, Lease, Description [Line Items]
Operating Lease Liabilities, Current	$ 4.8	$ 5.9
Vehicles and Equipment [Member]
Lessee, Lease, Description [Line Items]
Operating Lease, Weighted Average Remaining Lease Term	3 years	3 years
Operating Lease, Weighted Average Discount Rate, Percent	3.80%	3.10%
Land and Other [Member]
Lessee, Lease, Description [Line Items]
Operating Lease, Weighted Average Remaining Lease Term	27 years	27 years
Operating Lease, Weighted Average Discount Rate, Percent	4.50%	4.10%

Income Tax Expense - Reconciliation of Taxes from Federal Statutory Rate to Total Income Tax Expense (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2021

Dec. 31, 2020

Dec. 31, 2019

Income Before Non-Controlling Interest and Income Taxes

$ 110.9

$ 122.1

$ 178.9

Statutory Federal Income Tax Rate

21.00%

Income Taxes Computed at Statutory Federal Rate

$ 23.3

$ 25.6

$ 37.6

Increase (Decrease) in Tax Due to: [Abstract]

State Income Taxes – Net of Federal Income Tax Benefit

8.6

7.7

17.2

Production Tax Credits

(53.5)

(62.7)

(50.7)

Regulatory Differences – Excess Deferred Tax Benefit

^[1]

(9.5)

(9.9)

(8.8)

U.S. Water Services Sale of Stock Basis Difference

0.0

1.7

Non-controlling interest

6.3

2.7

0.0

Effective Income Tax Rate Reconciliation, Nondeductible Expense, Share-based Payment Arrangement, Amount

0.5

0.0

Total Income Tax Expense (Benefit)

(2.6)

(2.9)

(3.6)

$ (26.9)

$ (39.5)

$ (6.6)

Effective Tax Rate

(24.30%)

(32.40%)

(3.70%)

[1]	Excess deferred income taxes are being returned to customers under both the Average Rate Assumption Method and amortization periods as approved by regulators. (See Note 4. Regulatory Matters.)

Short-Term and Long-Term Debt - Short-Term Debt (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Debt Disclosure [Abstract]
Short-Term Debt - Outstanding	$ 214.2	$ 203.7
Short-Term Debt - Unamortized Debt Issuance Costs	0.2
Bank Lines of Credit [Member]
Lines of Credit [Line Items]
Maximum Borrowing Capacity	432.0	407.0
Standby Letters of Credit	31.5	22.3
Draws Outstanding	$ 159.7	$ 0.0

The carrying value as of the balance sheet date of the current portion of long-term obligations drawn from a line of credit, which is a bank's commitment to make loans up to a specific amount. Examples of items that might be included in the application of this element may consist of letters of credit, standby letters of credit, and revolving credit arrangements, under which borrowings can be made up to a maximum amount as of any point in time conditional on satisfaction of specified terms before, as of and after the date of drawdowns on the line. Includes short-term obligations that would normally be classified as current liabilities but for which (a) postbalance sheet date issuance of a long term obligation to refinance the short term obligation on a long term basis, or (b) the enterprise has entered into a financing agreement that clearly permits the enterprise to refinance the short-term obligation on a long term basis and the following conditions are met (1) the agreement does not expire within 1 year and is not cancelable by the lender except for violation of an objectively determinable provision, (2) no violation exists at the BS date, and (3) the lender has entered into the financing agreement is expected to be financially capable of honoring the agreement.

Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]

Regulatory Matters - MISO Return on Equity Complaints (Details) - FERC [Member]	Dec. 31, 2021
Loss Contingencies [Line Items]
FERC Authorized Return on Common Equity	10.02%
FERC Authorized Return on Equity Including Incentive Adder	10.52%

Employee Stock and Incentive Plans - Stock-Based Compensation (Details) shares in Millions	12 Months Ended
	Dec. 31, 2021 shares
Performance Shares [Member]
Stock-based Compensation [Line Items]
Vesting Period (Years)	3 years
Restricted Stock Units [Member]
Stock-based Compensation [Line Items]
Vesting Period (Years)	3 years
Employee Stock Purchase Plan (ESPP) [Member]
Stock-based Compensation [Line Items]
ESPP Discount	5.00%
Executive Long-Term Incentive Compensation Plan [Member]
Stock-based Compensation [Line Items]
Common Stock Reserved (Shares)	0.7
Shares Available for Issuance	0.7

Pension and Other Postretirement Benefit Plans - Unrecognized Postretirement Health and Life Costs (Details) - Postretirement Health and Life [Member] - USD ($)
$ in Millions

Dec. 31, 2021

Dec. 31, 2020

Net (Gain) Loss

^[1]

$ (12.7)

$ 23.0

Total Unrecognized Postretirement Health and Life Cost

(20.7)

(28.3)

$ (33.4)

$ (5.3)

[1]	Excludes gains, losses and contributions associated with irrevocable grantor trusts.

Income Tax Expense (Tables)

12 Months Ended

Dec. 31, 2021

Income Tax Disclosure [Abstract]

Income Tax Expense [Table Text Block]


Income Tax Expense
Year Ended December 31	2021	2020	2019
Millions
Current Income Tax Expense (a)
Federal	—	—	—
State	—	—	$0.1
Total Current Income Tax Expense	—	—	$0.1
Deferred Income Tax Expense (Benefit)
Federal (b)	$(37.2)	$(48.8)	$(27.8)

State	10.8	9.8	21.7

Investment Tax Credit Amortization	(0.5)	(0.5)	(0.6)
Total Deferred Income Tax Expense (Benefit)	$(26.9)	$(39.5)	$(6.7)
Total Income Tax Expense (Benefit)	$(26.9)	$(39.5)	$(6.6)

(a)For the years ended December 31, 2021, 2020 and 2019, the federal and state current tax expense was minimal due to NOLs which resulted from the bonus depreciation and related tax attributes from large wind projects. Federal and state NOLs are being carried forward to offset current and future taxable income.

(b)For the years ended December 31, 2021, 2020 and 2019, the federal tax benefit is primarily due to production tax credits.

Reconciliation of Taxes from Federal Statutory Rate to Total Income Tax Expense [Table Text Block]


Reconciliation of Taxes from Federal Statutory
Rate to Total Income Tax Expense
Year Ended December 31	2021		2020		2019
Millions
Income Before Non-Controlling Interest and Income Taxes	$110.9		$122.1		$178.9
Statutory Federal Income Tax Rate	21	%	21	%	21	%
Income Taxes Computed at Statutory Federal Rate	$23.3		$25.6		$37.6
Increase (Decrease) in Tax Due to:
State Income Taxes – Net of Federal Income Tax Benefit	8.6		7.7		17.2


Production Tax Credits	(53.5)		(62.7)		(50.7)
Regulatory Differences – Excess Deferred Tax Benefit (a)	(9.5)		(9.9)		(8.8)
U.S. Water Services Sale of Stock Basis Difference	—		—		1.7

Non-Controlling Interest	6.3		2.7		—
Share-Based Compensation	0.5		—		—
Other	(2.6)		(2.9)		(3.6)
Total Income Tax Expense (Benefit)	$(26.9)		$(39.5)		$(6.6)

(a)Excess deferred income taxes are being returned to customers under both the Average Rate Assumption Method and amortization periods as approved by regulators. (See Note 4. Regulatory Matters.)

Deferred Tax Assets and Liabilities [Table Text Block]


Deferred Income Tax Assets and Liabilities
As of December 31	2021	2020
Millions
Deferred Income Tax Assets
Employee Benefits and Compensation	$44.5	$67.6
Property-Related	54.8	61.4
NOL Carryforwards	67.5	60.7
Tax Credit Carryforwards	509.1	455.7
Power Sales Agreements	16.5	20.1
Regulatory Liabilities	101.5	107.7
Other	—	22.4
Gross Deferred Income Tax Assets	793.9	795.6
Deferred Income Tax Asset Valuation Allowance	(69.0)	(69.9)
Total Deferred Income Tax Assets	$724.9	$725.7
Deferred Income Tax Liabilities
Property-Related	$680.8	$691.5
Regulatory Asset for Benefit Obligations	54.9	71.5
Unamortized Investment Tax Credits	30.5	31.1
Partnership Basis Differences	106.3	86.7
Regulatory Assets	30.0	32.6
Other	8.1	8.0
Total Deferred Income Tax Liabilities	$910.6	$921.4
Net Deferred Income Taxes (a)	$185.7	$195.7

(a)Recorded as a net long-term Deferred Income Tax liability on the Consolidated Balance Sheet.

NOL and Tax Credit Carryforwards [Table Text Block]


NOL and Tax Credit Carryforwards
As of December 31	2021	2020
Millions
Federal NOL Carryforwards (a)	$177.3	$197.5
Federal Tax Credit Carryforwards	$416.4	$362.9
State NOL Carryforwards (a)	$506.9	$270.1
State Tax Credit Carryforwards (b)	$24.2	$23.4

(a)Pre-tax amounts.

(b)Net of a $68.6 million valuation allowance as of December 31, 2021 ($69.4 million as of December 31, 2020).

Gross Unrecognized Income Tax Benefits [Table Text Block]


Gross Unrecognized Income Tax Benefits	2021	2020	2019
Millions
Balance at January 1	$1.4	$1.4	$1.6
Additions for Tax Positions Related to the Current Year	—	0.1	0.1
Additions for Tax Positions Related to Prior Years	—	—	0.1
Reductions for Tax Positions Related to Prior Years	(0.1)	(0.1)	(0.4)

Lapse of Statute	—	—	—
Balance as of December 31	$1.3	$1.4	$1.4

Consolidated Statement of Equity - USD ($) $ in Millions	Total	Common Stock [Member]	Accumulated Other Comprehensive Loss [Member]	Retained Earnings [Member]	Non-Controlling Interest in Subsidiaries [Member]
Balance, Beginning of Period at Dec. 31, 2018		$ 1,428.5	$ (27.3)	$ 754.6	$ 0.0
Consolidated Statement of Equity [Roll Forward]
Common Stock Issued		8.2
Unrealized Gain (Loss) on Debt Securities	$ 0.2		0.2
Defined Benefit Pension and Other Postretirement Plans	3.5		3.5
Net Loss Attributable to Non-Controlling Interest	(0.1)				(0.1)
Reclassification of Redeemable Non-Controlling Interest to Current Liabilities					0.0
Distributions to Non-Controlling Interest					0.0
Net Income Attributable to ALLETE	185.6			185.6
Common Stock Dividends	121.4			(121.4)
Adjustment of Redeemable Non-Controlling Interest				0.0
Proceeds from Non-Controlling Interest - Net of Issuance Costs	103.8				103.8
Balance, Ending of Period at Dec. 31, 2019	$ 2,335.6	1,436.7	(23.6)	818.8	103.7
Consolidated Statement of Equity [Roll Forward]
Dividends Per Share of Common Stock	$ 2.35
Common Stock Issued		24.2
Unrealized Gain (Loss) on Debt Securities	$ 0.1		0.1
Defined Benefit Pension and Other Postretirement Plans	(7.6)		(7.6)
Net Loss Attributable to Non-Controlling Interest	(12.6)				(12.6)
Reclassification of Redeemable Non-Controlling Interest to Current Liabilities					0.0
Distributions to Non-Controlling Interest					0.0
Net Income Attributable to ALLETE	174.2			174.2
Common Stock Dividends	128.2			(128.2)
Adjustment of Redeemable Non-Controlling Interest				0.0
Proceeds from Non-Controlling Interest - Net of Issuance Costs	414.5				414.5
Balance, Ending of Period at Dec. 31, 2020	$ 2,800.2	1,460.9	(31.1)	864.8	505.6
Consolidated Statement of Equity [Roll Forward]
Dividends Per Share of Common Stock	$ 2.47
Common Stock Issued		75.8
Unrealized Gain (Loss) on Debt Securities	$ (0.1)		(0.1)
Defined Benefit Pension and Other Postretirement Plans	7.4		7.4
Net Loss Attributable to Non-Controlling Interest	(31.4)				(31.4)
Reclassification of Redeemable Non-Controlling Interest to Current Liabilities					(28.8)
Distributions to Non-Controlling Interest					(3.1)
Net Income Attributable to ALLETE	169.2			169.2
Common Stock Dividends	131.9			(131.9)
Adjustment of Redeemable Non-Controlling Interest				(1.9)
Proceeds from Non-Controlling Interest - Net of Issuance Costs	90.9				90.9
Balance, Ending of Period at Dec. 31, 2021	$ 2,946.3	$ 1,536.7	$ (23.8)	$ 900.2	$ 533.2
Consolidated Statement of Equity [Roll Forward]
Dividends Per Share of Common Stock	$ 2.52

Pension and Other Postretirement Benefit Plans

12 Months Ended

Dec. 31, 2021

Retirement Benefits [Abstract]

Pension and Other Postretirement Benefit Plans [Text Block]

PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS

We have noncontributory union, non-union and combined retiree defined benefit pension plans covering eligible employees. The combined retiree defined benefit pension plan was created in 2016, to include all union and non-union retirees from the existing plans as of January 1, 2016. The plans provide defined benefits based on years of service and final average pay. We contributed $10.3 million in cash to the plans in 2021 ($10.7 million in 2020; $10.4 million in 2019). We also have a defined contribution RSOP covering substantially all employees. The 2021 plan year employer contributions, which are made through the employee stock ownership plan portion of the RSOP, totaled $11.5 million ($11.2 million for the 2020 plan year; $10.8 million for the 2019 plan year). (See Note 9. Common Stock and Earnings Per Share and Note 12. Employee Stock and Incentive Plans.)

The non-union defined benefit pension plan was frozen in 2018, and does not allow further crediting of service or earnings to the plan. Further, it is closed to new participants. The Minnesota Power union defined benefit pension plan is also closed to new participants, and the SWL&P union defined benefit pension plan was closed to new participants effective February 1, 2022.

We have postretirement health care and life insurance plans covering eligible employees. In 2010, the postretirement health care plan was closed to employees hired after January 31, 2011, and the eligibility requirements were amended. In 2014, the postretirement life plan was amended to close the plan to non-union employees retiring after December 31, 2015, and in 2018, the postretirement life plan was amended to limit the benefit level for union employees retiring after December 31, 2018. The postretirement health and life plans are contributory with participant contributions adjusted annually. Postretirement health and life benefits are funded through a combination of Voluntary Employee Benefit Association trusts (VEBAs), established under section 501(c)(9) of the Internal Revenue Code, and irrevocable grantor trusts. In 2021, no contributions were made to the VEBAs (none in 2020; none in 2019) and no contributions were made to the grantor trusts (none in 2020; none in 2019).

Management considers various factors when making funding decisions such as regulatory requirements, actuarially determined minimum contribution requirements and contributions required to avoid benefit restrictions for the pension plans. Contributions are based on estimates and assumptions which are subject to change. We do not expect to make any contributions to the defined benefit pension plans in 2022, and we do not expect to make any contributions to the defined benefit postretirement health and life plans in 2022.

Accounting for defined benefit pension and other postretirement benefit plans requires that employers recognize on a prospective basis the funded status of their defined benefit pension and other postretirement plans on their balance sheet and recognize as a component of other comprehensive income, net of tax, the gains or losses and prior service costs or credits that arise during the period but are not recognized as components of net periodic benefit cost.

The defined benefit pension and postretirement health and life benefit expense (credit) recognized annually by our regulated utilities are expected to be recovered (refunded) through rates filed with our regulatory jurisdictions. As a result, these amounts that are required to otherwise be recognized in accumulated other comprehensive income have been recognized as a long-term regulatory asset (regulatory liability) on the Consolidated Balance Sheet, in accordance with the accounting standards for the effect of certain types of regulation applicable to our Regulated Operations. The defined benefit pension and postretirement health and life benefit expense (credits) associated with our other operations are recognized in accumulated other comprehensive income.

NOTE 11. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (Continued)


Pension Obligation and Funded Status
As of December 31	2021	2020
Millions
Accumulated Benefit Obligation	$875.5	$931.2
Change in Benefit Obligation
Obligation, Beginning of Year	$965.7	$854.0
Service Cost	11.0	10.7
Interest Cost	24.6	27.9

Plan Curtailments	(1.4)	—
Actuarial (Gain) Loss (a)	(39.0)	118.7
Benefits Paid	(56.5)	(54.4)
Participant Contributions	7.3	8.8
Obligation, End of Year	$911.7	$965.7
Change in Plan Assets
Fair Value, Beginning of Year	$759.4	$699.6
Actual Return on Plan Assets	23.1	93.0
Employer Contribution (b)	19.7	21.2
Benefits Paid	(56.5)	(54.4)
Fair Value, End of Year	$745.7	$759.4
Funded Status, End of Year	$(166.0)	$(206.3)

Net Pension Amounts Recognized in Consolidated Balance Sheet Consist of:
Current Liabilities	$(2.1)	$(2.2)
Non-Current Liabilities	$(163.9)	$(204.1)

(a) Actuarial (gain) loss was primarily the result of increases in discount rates in 2021 compared to decreases in 2020.

(b) Includes Participant Contributions noted above.

The pension costs that are reported as a component within the Consolidated Balance Sheet, reflected in long-term regulatory assets or liabilities and accumulated other comprehensive income, consist of a net loss of $260.2 million and prior service credit of $1.0 million as of December 31, 2021 (net loss of $299.0 million and prior service credit of $1.1 million as of December 31, 2020).

NOTE 11. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (Continued)


Reconciliation of Net Pension Amounts Recognized in Consolidated Balance Sheet
As of December 31	2021	2020
Millions
Net Loss	$(260.2)	$(299.0)
Prior Service Credit	1.0	1.1
Accumulated Contributions in Excess of Net Periodic Benefit Cost (Prepaid Pension Asset)	93.2	91.6
Total Net Pension Amounts Recognized in Consolidated Balance Sheet	$(166.0)	$(206.3)


Components of Net Periodic Pension Cost
Year Ended December 31	2021	2020	2019
Millions
Service Cost	$11.0	$10.7	$9.3
Non-Service Cost Components (a)
Interest Cost	24.6	27.9	31.9
Expected Return on Plan Assets	(43.4)	(42.7)	(44.2)
Amortization of Loss	18.8	12.8	7.5
Amortization of Prior Service Credit	(0.2)	(0.2)	(0.1)
Net Pension Cost	$10.8	$8.5	$4.4

(a)These components of net periodic pension cost are included in the line item “Other” under Other Income (Expense) on the Consolidated Statement of Income.


Other Changes in Pension Plan Assets and Benefit Obligations Recognized in Other Comprehensive Income and Regulatory Assets or Liabilities
Year Ended December 31	2021	2020
Millions
Net (Gain) Loss	$(20.1)	$68.4
Amortization of Prior Service Credit	0.2	0.2

Amortization of Loss	(18.8)	(12.8)
Total Recognized in Other Comprehensive Income and Regulatory Assets or Liabilities	$(38.7)	$55.8


Information for Pension Plans with an Accumulated Benefit Obligation in Excess of Plan Assets
As of December 31	2021	2020
Millions
Projected Benefit Obligation	$911.7	$965.7
Accumulated Benefit Obligation	$875.5	$931.2
Fair Value of Plan Assets	$745.7	$759.4

NOTE 11. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (Continued)


Postretirement Health and Life Obligation and Funded Status
As of December 31	2021	2020
Millions
Change in Benefit Obligation
Obligation, Beginning of Year	$167.6	$149.8
Service Cost	3.6	3.3
Interest Cost	4.4	5.0
Actuarial (Gain) Loss (a)	(19.7)	19.2
Benefits Paid	(10.6)	(12.6)
Participant Contributions	2.9	3.2

Plan Curtailments	—	(0.3)

Obligation, End of Year	$148.2	$167.6
Change in Plan Assets
Fair Value, Beginning of Year	$186.0	$173.7
Actual Return on Plan Assets	22.8	20.9
Employer Contribution	0.7	0.8
Participant Contributions	2.9	3.2
Benefits Paid	(10.6)	(12.6)
Fair Value, End of Year	$201.8	$186.0
Funded Status, End of Year	$53.6	$18.4

Net Postretirement Health and Life Amounts Recognized in Consolidated Balance Sheet Consist of:
Non-Current Assets	$64.8	$34.2
Current Liabilities	$(1.4)	$(0.6)
Non-Current Liabilities	$(9.8)	$(15.2)

(a)Actuarial (gain) loss was primarily the result of increases in discount rates in 2021 compared to decreases in 2020.

According to the accounting standards for retirement benefits, only assets in the VEBAs are treated as plan assets in the preceding table for the purpose of determining funded status. In addition to the postretirement health and life assets reported in the previous table, we had $13.2 million in irrevocable grantor trusts included in Other Investments on the Consolidated Balance Sheet as of December 31, 2021 ($20.4 million as of December 31, 2020).


Unrecognized Postretirement Health and Life Costs
As of December 31	2021	2020
Millions
Net (Gain) Loss	$(12.7)	$23.0
Prior Service Credit	(20.7)	(28.3)

Total Unrecognized Postretirement Health and Life Cost	$(33.4)	$(5.3)

NOTE 11. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (Continued)


Reconciliation of Net Postretirement Health and Life Amounts Recognized in Consolidated Balance Sheet
As of December 31	2021	2020
Millions
Net Gain (Loss) (a)	$12.7	$(23.0)
Prior Service Credit	20.7	28.3
Accumulated Net Periodic Benefit Cost in Excess of Contributions (a)	20.2	13.1
Total Net Postretirement Health and Life Amounts Recognized in Consolidated Balance Sheet	$53.6	$18.4

(a)Excludes gains, losses and contributions associated with irrevocable grantor trusts.


Components of Net Periodic Postretirement Health and Life Cost
Year Ended December 31	2021	2020	2019
Millions
Service Cost	$3.6	$3.3	$3.9
Non-Service Cost Components (a)
Interest Cost	4.4	5.0	7.3
Expected Return on Plan Assets	(9.9)	(9.7)	(10.5)
Amortization of Loss	3.0	1.0	0.5
Amortization of Prior Service Credit	(7.6)	(8.0)	(2.8)

Effect of Plan Curtailment	—	(0.3)	(2.1)
Net Postretirement Health and Life Credit	$(6.5)	$(8.7)	$(3.7)

(a)These components of net periodic postretirement health and life cost are included in the line item “Other” under Other Income (Expense) on the Consolidated Statement of Income.


Other Changes in Postretirement Benefit Plan Assets and Benefit Obligations Recognized in Other Comprehensive Income and Regulatory Assets or Liabilities
Year Ended December 31	2021	2020
Millions
Net (Gain) Loss	$(32.7)	$8.1

Amortization of Prior Service Credit	7.6	8.0

Amortization of Loss	(3.0)	(1.0)

Total Recognized in Other Comprehensive Income and Regulatory Assets or Liabilities	$(28.1)	$15.1


Estimated Future Benefit Payments	Pension	Postretirement Health and Life
Millions
2022	$54.6	$8.4
2023	$54.4	$8.4
2024	$54.4	$8.4
2025	$53.8	$8.2
2026	$53.1	$8.1
Years 2027 – 2031	$257.2	$41.6

NOTE 11. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (Continued)


Weighted Average Assumptions Used to Determine Benefit Obligation
As of December 31	2021	2020
Discount Rate
Pension	3.05%	2.62%
Postretirement Health and Life	3.09%	2.70%
Rate of Compensation Increase	3.58%	3.61%
Health Care Trend Rates
Trend Rate	5.66%	5.81%
Ultimate Trend Rate	4.50%	4.50%
Year Ultimate Trend Rate Effective	2038	2038


Weighted Average Assumptions Used to Determine Net Periodic Benefit Costs
Year Ended December 31	2021	2020	2019
Discount Rate
Pension	2.87%	3.52%	4.67%
Postretirement Health and Life	2.70%	3.45%	4.47%
Expected Long-Term Return on Plan Assets (a)
Pension	6.50%	6.75%	7.25%
Postretirement Health and Life	5.85%	6.08%	6.51%
Rate of Compensation Increase	3.62%	4.06%	4.04%

In establishing the expected long-term rate of return on plan assets, we determine the long-term historical performance of each asset class, adjust these for current economic conditions, and utilizing the target allocation of our plan assets, forecast the expected long-term rate of return.

The discount rate is computed using a bond matching study which utilizes a portfolio of high quality bonds that produce cash flows similar to the projected costs of our pension and other postretirement plans.

The Company utilizes actuarial assumptions about mortality to calculate the pension and postretirement health and life benefit obligations. The mortality assumptions used to calculate our pension and other postretirement benefit obligations as of December 31, 2021, considered a modified PRI-2012 mortality table and MP-2021 mortality projection scale.

NOTE 11. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (Continued)


Actual Plan Asset Allocations	Pension		Postretirement Health and Life (a)
	2021	2020	2021	2020
Equity Securities	49%	36%	70%	67%
Fixed Income Securities	48%	61%	29%	32%
Private Equity	—	1	1%	1%
Real Estate	3%	2%	—	—
	100%	100%	100%	100%

(a)Includes VEBAs and irrevocable grantor trusts.

There were no shares of ALLETE common stock included in pension plan equity securities as of December 31, 2021 (no shares as of December 31, 2020).

The defined benefit pension plans have adopted a dynamic asset allocation strategy (glide path) that increases the invested allocation to fixed income assets as the funding level of the plan increases to better match the sensitivity of the plan’s assets and liabilities to changes in interest rates. This is expected to reduce the volatility of reported pension plan expenses. The postretirement health and life plans’ assets are diversified to achieve strong returns within managed risk. Equity securities are diversified among domestic companies with large, mid and small market capitalizations, as well as investments in international companies. The majority of debt securities are made up of investment grade bonds.

Following are the current targeted allocations as of December 31, 2021:


Plan Asset Target Allocations	Pension		Postretirement Health and Life (a)
Equity Securities	49	%	60	%
Fixed Income Securities	49	%	37	%
Private Equity	1	%	—
Real Estate	1	%	3	%
	100	%	100	%

(a)Includes VEBAs and irrevocable grantor trusts.

Fair Value

Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). We utilize market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated, or generally unobservable. We primarily apply the market approach for recurring fair value measurements and endeavor to utilize the best available information. Accordingly, we utilize valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. These inputs, which are used to measure fair value, are prioritized through the fair value hierarchy. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). (See Note 6. Fair Value.)

NOTE 11. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (Continued)

Fair Value (Continued)

Pension Fair Value


	Fair Value as of December 31, 2021
Recurring Fair Value Measures	Level 1	Level 2	Level 3	Total
Millions
Assets:
Equity Securities:
U.S. Large-cap (a)	—	$113.8	—	$113.8
U.S. Mid-cap Growth (a)	—	47.6	—	47.6
U.S. Small-cap (a)	—	46.2	—	46.2

International	—	158.2	—	158.2



Fixed Income Securities (a)	—	346.1	—	346.1
Cash and Cash Equivalents	$12.2	—	—	12.2

Private Equity Funds	—	—	—	—
Real Estate	—	—	$21.6	21.6
Total Fair Value of Assets	$12.2	$711.9	$21.6	$745.7

(a)The underlying investments consist of actively-managed funds managed to achieve the returns of certain U.S. equity and fixed income securities indexes.


Recurring Fair Value Measures
Activity in Level 3	Private Equity Funds	Real Estate
Millions
Balance as of December 31, 2020	$7.0	$18.0
Actual Return on Plan Assets	(3.5)	3.6
Purchases, Sales, and Settlements – Net	(3.5)	—
Balance as of December 31, 2021	—	$21.6


	Fair Value as of December 31, 2020
Recurring Fair Value Measures	Level 1	Level 2	Level 3	Total
Millions
Assets:
Equity Securities:
U.S. Large-cap (a)	—	$91.7	—	$91.7
U.S. Mid-cap Growth (a)	—	40.0	—	40.0
U.S. Small-cap (a)	—	40.7	—	40.7

International	—	97.1	—	97.1



Fixed Income Securities (a)	—	461.7	—	461.7
Cash and Cash Equivalents	$3.2	—	—	3.2

Private Equity Funds	—	—	$7.0	7.0
Real Estate	—	—	18.0	18.0
Total Fair Value of Assets	$3.2	$731.2	$25.0	$759.4

(a)The underlying investments consist of actively-managed funds managed to achieve the returns of certain U.S. equity and fixed income securities indexes.

NOTE 11. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (Continued)

Fair Value (Continued)


Recurring Fair Value Measures
Activity in Level 3	Private Equity Funds	Real Estate
Millions
Balance as of December 31, 2019	$8.0	$18.0
Actual Return on Plan Assets	0.1	—
Purchases, Sales, and Settlements – Net	(1.1)	—
Balance as of December 31, 2020	$7.0	$18.0

Postretirement Health and Life Fair Value


	Fair Value as of December 31, 2021
Recurring Fair Value Measures	Level 1	Level 2	Level 3	Total
Millions
Assets:
Equity Securities: (a)
U.S. Large-cap	$40.1	—	—	$40.1
U.S. Mid-cap Growth	37.3	—	—	37.3
U.S. Small-cap	19.3	—	—	19.3
International	43.7	—	—	43.7
Fixed Income Securities:
Mutual Funds	56.7	—	—	56.7
Debt Securities	—	$1.8	—	1.8
Cash and Cash Equivalents	0.9	—	—	0.9

Private Equity Funds	—	—	$2.0	2.0
Total Fair Value of Assets	$198.0	$1.8	$2.0	$201.8

(a)The underlying investments consist of mutual funds (Level 1).


Recurring Fair Value Measures
Activity in Level 3			Private Equity Funds
Millions
Balance as of December 31, 2020			$1.7
Actual Return on Plan Assets			0.8
Purchases, Sales, and Settlements – Net			(0.5)
Balance as of December 31, 2021			$2.0

NOTE 11. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (Continued)

Fair Value (Continued)


	Fair Value as of December 31, 2020
Recurring Fair Value Measures	Level 1	Level 2	Level 3	Total
Millions
Assets:
Equity Securities: (a)
U.S. Large-cap	$34.2	—	—	$34.2
U.S. Mid-cap Growth	31.4	—	—	31.4
U.S. Small-cap	16.6	—	—	16.6
International	41.5	—	—	41.5
Fixed Income Securities:
Mutual Funds	57.3	—	—	57.3
Debt Securities	—	$2.2	—	2.2
Cash and Cash Equivalents	1.1	—	—	1.1

Private Equity Funds	—	—	$1.7	1.7
Total Fair Value of Assets	$182.1	$2.2	$1.7	$186.0

(a)The underlying investments consist of mutual funds (Level 1).


Recurring Fair Value Measures
Activity in Level 3			Private Equity Funds
Millions
Balance as of December 31, 2019			$1.7
Actual Return on Plan Assets			—
Purchases, Sales, and Settlements – Net			—
Balance as of December 31, 2020			$1.7

Accounting and disclosure requirements for the Medicare Prescription Drug, Improvement and Modernization Act of 2003 (Act) provide guidance for employers that sponsor postretirement health care plans that provide prescription drug benefits. We provide a fully insured postretirement health benefit, including a prescription drug benefit, which qualifies us for a federal subsidy under the Act. The federal subsidy is reflected in the premiums charged to us by the insurance company.

The entire disclosure for retirement benefits.

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Equity Investments (Tables)

12 Months Ended

Dec. 31, 2021

Equity Investments [Table Text Block]


ALLETE’s Investment in ATC
Year Ended December 31	2021	2020
Millions
Equity Investment Beginning Balance	$149.0	$141.6
Cash Investments	—	2.7
Equity in ATC Earnings	21.3	22.3
Distributed ATC Earnings	(17.2)	(18.9)

Amortization of the Remeasurement of Deferred Income Taxes	1.4	1.3
Equity Investment Ending Balance	$154.5	$149.0


ATC Summarized Financial Data
Balance Sheet Data
As of December 31	2021	2020
Millions
Current Assets	$89.8	$92.8
Non-Current Assets	5,628.1	5,400.5
Total Assets	$5,717.9	$5,493.3
Current Liabilities	$436.9	$310.8
Long-Term Debt	2,513.0	2,512.2
Other Non-Current Liabilities	422.0	378.2
Members’ Equity	2,346.0	2,292.1
Total Liabilities and Members’ Equity	$5,717.9	$5,493.3


Income Statement Data
Year Ended December 31	2021	2020	2019
Millions
Revenue	$754.8	$758.1	$744.4
Operating Expense	376.2	372.4	373.5
Other Expense	113.9	110.9	110.5
Net Income	$264.7	$274.8	$260.4
ALLETE’s Equity in Net Income	$21.3	$22.3	$21.7

Equity Investments [Table Text Block]


ALLETE’s Investment in Nobles 2
Millions
Equity Investment Balance as of December 31, 2020			$152.2
Cash Investments			17.6
Equity in Nobles 2 Earnings (a)			(1.3)
Distributed Nobles 2 Earnings			(5.0)
Equity Investment Balance as of December 31, 2021			$163.5

(a)The Company also recorded net loss attributable to non-controlling interest of $6.6 million related to its investment in Nobles 2

Fair Value

12 Months Ended

Dec. 31, 2021

Fair Value Disclosures [Abstract]

Fair Value [Text Block]

FAIR VALUE

Level 1 — Quoted prices are available in active markets for identical assets or liabilities as of the reported date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. This category includes primarily equity securities.

Level 2 — Pricing inputs are other than quoted prices in active markets, but are either directly or indirectly observable as of the reported date. The types of assets and liabilities included in Level 2 are typically either comparable to actively traded securities or contracts, such as treasury securities with pricing interpolated from recent trades of similar securities, or priced with models using highly observable inputs, such as commodity options priced using observable forward prices and volatilities. This category includes deferred compensation and fixed income securities.

Level 3 — Significant inputs that are generally less observable from objective sources. The types of assets and liabilities included in Level 3 are those with inputs requiring significant management judgment or estimation, such as the complex and subjective models and forecasts used to determine the fair value.

NOTE 6. FAIR VALUE (Continued)

The following tables set forth by level within the fair value hierarchy, our assets and liabilities that were accounted for at fair value on a recurring basis as of December 31, 2021, and December 31, 2020. Each asset and liability is classified based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment, which may affect the valuation of these assets and liabilities and their placement within the fair value hierarchy levels. The estimated fair value of Cash and Cash Equivalents listed on the Consolidated Balance Sheet approximates the carrying amount and therefore is excluded from the recurring fair value measures in the following tables.


	Fair Value as of December 31, 2021
Recurring Fair Value Measures	Level 1	Level 2	Level 3	Total
Millions
Assets:
Investments (a)
Available-for-sale – Equity Securities	$8.9	—	—	$8.9
Available-for-sale – Corporate and Governmental Debt Securities (b)	—	$6.2	—	6.2
Cash Equivalents	2.5	—	—	2.5
Total Fair Value of Assets	$11.4	$6.2	—	$17.6

Liabilities:
Deferred Compensation (c)	—	$18.0	—	$18.0

Total Fair Value of Liabilities	—	$18.0	—	$18.0
Total Net Fair Value of Assets (Liabilities)	$11.4	$(11.8)	—	$(0.4)

(a)Included in Other Non-Current Assets on the Consolidated Balance Sheet.

(b)As of December 31, 2021, the aggregate amount of available-for-sale corporate and governmental debt securities maturing in one year or less was $1.0 million, in one year to less than three years was $2.3 million, in three years to less than five years was $2.1 million and in five or more years was $0.8 million.

(c)Included in Other Non-Current Liabilities on the Consolidated Balance Sheet.


	Fair Value as of December 31, 2020
Recurring Fair Value Measures	Level 1	Level 2	Level 3	Total
Millions
Assets:
Investments (a)
Available-for-sale – Equity Securities	$7.2	—	—	$7.2
Available-for-sale – Corporate and Governmental Debt Securities	—	$10.4	—	10.4
Cash Equivalents	5.5	—	—	5.5
Total Fair Value of Assets	$12.7	$10.4	—	$23.1

Liabilities: (b)
Deferred Compensation	—	$21.0	—	$21.0

Total Fair Value of Liabilities	—	$21.0	—	$21.0
Total Net Fair Value of Assets (Liabilities)	$12.7	$(10.6)	—	$2.1

(a)Included in Other Non-Current Assets on the Consolidated Balance Sheet.

(b)Included in Other Non-Current Liabilities on the Consolidated Balance Sheet.

The Company’s policy is to recognize transfers in and transfers out of Levels as of the actual date of the event or change in circumstances that caused the transfer. For the years ended December 31, 2021 and 2020, there were no transfers in or out of Levels 1, 2 or 3.

Fair Value of Financial Instruments. With the exception of the item listed in the following table, the estimated fair value of all financial instruments approximates the carrying amount. The fair value for the item listed in the following table was based on quoted market prices for the same or similar instruments (Level 2).

NOTE 6. FAIR VALUE (Continued)


Financial Instruments	Carrying Amount	Fair Value
Millions
Short-Term and Long-Term Debt (a)
December 31, 2021	$1,986.4	$2,192.6
December 31, 2020	$1,806.4	$2,122.0

(a) Excludes unamortized debt issuance costs.

Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis. Non-financial assets such as equity method investments, goodwill, intangible assets, and property, plant and equipment are measured at fair value when there is an indicator of impairment and recorded at fair value only when an impairment is recognized.

Equity Method Investments. The aggregate carrying amount of our equity investments was $318.0 million as of December 31, 2021 ($301.2 million as of December 31, 2020). The Company assesses our equity investments in ATC and Nobles 2 for impairment whenever events or changes in circumstances indicate that the carrying amount of our investments may not be recoverable. For the years ended December 31, 2021 and 2020, there were no indicators of impairment. (See Note 5. Equity Investments.)

Property, Plant and Equipment. The Company assesses the impairment of property, plant, and equipment whenever events or changes in circumstances indicate that the carrying amount of property, plant, and equipment assets may not be recoverable. (See Note 1. Operations and Significant Accounting Policies.) For the years ended December 31, 2021, and 2020, there was no impairment of property, plant, and equipment.

We believe that long-standing ratemaking practices approved by applicable state and federal regulatory commissions allow for the recovery of the remaining book value of retired plant assets. Minnesota Power’s 2015 IRP contained steps in Minnesota Power’s EnergyForward plan including the economic idling of Taconite Harbor Units 1 and 2 in 2016, and the ceasing of coal-fired operations at Taconite Harbor in 2020. As of December 31, 2021, Taconite Harbor had a net book value of approximately $45 million. The MPUC order for the 2015 IRP also directed Minnesota Power to retire Boswell Units 1 and 2, which occurred in the fourth quarter of 2018. As part of the 2016 general retail rate case, the MPUC allowed recovery of the remaining book value of Boswell Units 1 and 2 through 2022. In its latest IRP filing, Minnesota Power proposed retiring Boswell Unit 3 by 2030 and transforming Boswell Unit 4 to be coal-free by 2035. Boswell Unit 3 and Unit 4 have a net book value of approximately $245 million and $435 million, respectively, as of December 31, 2021. (See Note 4. Regulatory Matters.) We do not expect to record any impairment charge as a result of these operating changes at Taconite Harbor and Boswell. In addition, we expect to be able to continue depreciating these assets for at least their established remaining useful lives; however, we are unable to predict the impact of regulatory outcomes resulting in changes to their established remaining useful lives.

The entire disclosure for the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments as well as disclosures related to the fair value of non-financial assets and liabilities. Such disclosures about the financial instruments, assets, and liabilities would include: (1) the fair value of the required items together with their carrying amounts (as appropriate); (2) for items for which it is not practicable to estimate fair value, disclosure would include: (a) information pertinent to estimating fair value (including, carrying amount, effective interest rate, and maturity, and (b) the reasons why it is not practicable to estimate fair value; (3) significant concentrations of credit risk including: (a) information about the activity, region, or economic characteristics identifying a concentration, (b) the maximum amount of loss the entity is exposed to based on the gross fair value of the related item, (c) policy for requiring collateral or other security and information as to accessing such collateral or security, and (d) the nature and brief description of such collateral or security; (4) quantitative information about market risks and how such risks are managed; (5) for items measured on both a recurring and nonrecurring basis information regarding the inputs used to develop the fair value measurement; and (6) for items presented in the financial statement for which fair value measurement is elected: (a) information necessary to understand the reasons for the election, (b) discussion of the effect of fair value changes on earnings, (c) a description of [similar groups] items for which the election is made and the relation thereof to the balance sheet, the aggregate carrying value of items included in the balance sheet that are not eligible for the election; (7) all other required (as defined) and desired information.

Jointly-Owned Facilities and Assets [Abstract]

Fair Value - Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis [Line Items]
Impairment of Long-Lived Assets Held-for-use	$ 0.0	$ 0.0	$ 0.0
Equity Investments	318.0	301.2
Taconite Harbor [Member] \| Resource Package [Member] \| MPUC [Member]
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis [Line Items]
Net Book Value	45.0
Boswell Unit 3 [Member] \| 2021 Integrated Resource Plan [Member] \| MPUC [Member]
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis [Line Items]
Net Book Value	245.0
Boswell Unit 4 [Member] \| 2021 Integrated Resource Plan [Member] \| MPUC [Member]
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis [Line Items]
Net Book Value	435.0
ATC [Member]
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis [Line Items]
Equity Investments	154.5	149.0	$ 141.6
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis [Member] \| Corporate and Other [Member]
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis [Line Items]
Impairment of Long-Lived Assets Held-for-use	0.0
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis [Member] \| ATC [Member] \| Regulated Operations [Member]
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis [Line Items]
Equity Method Investment, Indicators of Impairment	$ 0.0	$ 0.0

Jointly-Owned Facilities and Assets

12 Months Ended

Dec. 31, 2021

Jointly-Owned Facilities and Assets [Text Block]

JOINTLY-OWNED FACILITIES AND ASSETSBoswell Unit 4. Minnesota Power owns 80 percent of the 585 MW Boswell Unit 4. While Minnesota Power operates the plant, certain decisions about the operations of Boswell Unit 4 are subject to the oversight of a committee on which it and WPPI Energy, the owner of the remaining 20 percent, have equal representation and voting rights. Each owner must provide its own financing and is obligated to its ownership share of operating costs. Minnesota Power’s share of operating expenses for Boswell Unit 4 is included in Operating Expenses on the Consolidated Statement of Income.

NOTE 3. JOINTLY-OWNED FACILITIES AND ASSETS (Continued)

Minnesota Power’s investments in jointly-owned facilities and assets and the related ownership percentages are as follows:


Regulated Utility Plant	Plant in Service	Accumulated Depreciation	Construction Work in Progress	% Ownership
Millions
As of December 31, 2021
Boswell Unit 4	$682.7	$311.1	$30.1	80
Transmission Assets	101.0	18.5	—	9.3 - 14.7
Total	$783.7	$329.6	$30.1
As of December 31, 2020
Boswell Unit 4	$663.8	$288.8	$15.0	80
Transmission Assets	101.0	16.0	—	9.3 - 14.7
Total	$764.8	$304.8	$15.0

Regulatory Matters - Regulatory Assets and Liabilities (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2021

Dec. 31, 2020

Regulatory Assets and Liabilities Currently Earning a Return

With the exception of the regulatory asset for Boswell Units 1 and 2 net plant and equipment, no other regulatory assets are currently earning a return.

$ 511.8

$ 480.9

8.6

7.6

Total Regulatory Liabilities

536.1

524.8

544.7

532.4

Transmission Formula Rates [Member]

^[1]

3.1

2.9

Income Taxes [Member]

Wholesale and Retail Contra AFUDC [Member]

^[2]

353.4

375.3

Plant Removal Obligations [Member]

^[3]

83.7

86.6

Pension and Other Postretirement Plans Costs [Member]

^[4]

52.6

41.2

North Dakota Investment Tax Credits [Member]

^[5]

28.1

4.4

Conservation Improvement Program [Member]

^[6]

12.2

12.0

^[7]

0.0

1.5

Other [Member]

^[1]

0.5

1.0

5.7

3.8

Boswell 1 & 2 [Member]

^[8]

0.4

0.0

Fuel Adjustment Clause

Pension and Other Postretirement Plans Costs [Member]

^[1],[9]

5.0

3.7

^[5]

226.4

259.7

Income Taxes [Member]

Asset Retirement Obligation [Member]

^[2]

104.7

113.7

^[10]

33.1

31.6

Boswell 1 & 2 [Member]

Manufactured Gas Plant [Member]

^[8]

0.0

5.0

PPACA Income Tax Deferral [Member]

^[11]

17.0

8.8

4.3

4.5

Other [Member]

Cost Recovery Riders [Member]

4.3

3.6

Conservation Improvement Program [Member]

^[12]

63.2

54.0

^[7]

2.4

0.0

Fuel Adjustment Clause

Commitments and Contingencies Disclosure [Abstract]

^[9]

$ 56.4

$ 0.0

[1]	Current regulatory liabilities are presented within Other Current Liabilities on the Consolidated Balance Sheet.
[2]	These costs represent the difference between deferred income taxes recognized for financial reporting purposes and amounts previously billed to our customers. The balances will primarily decrease over the remaining life of the related temporary differences.
[3]	Wholesale and retail contra AFUDC represents amortization to offset AFUDC Equity and Debt recorded during the construction period of our cost recovery rider projects prior to placing the projects in service. The regulatory liability will decrease over the remaining depreciable life of the related asset.
[4]	Non-legal plant removal obligations included in retail customer rates that have not yet been incurred.
[5]	Defined benefit pension and other postretirement items included in our Regulated Operations, which are otherwise required to be recognized in accumulated other comprehensive income as actuarial gains and losses as well as prior service costs and credits, are recognized as regulatory assets or regulatory liabilities on the Consolidated Balance Sheet. The asset or liability will decrease as the deferred items are amortized and recognized as components of net periodic benefit cost. (See Note 11. Pension and Other Postretirement Benefit Plans.)
[6]	North Dakota investment tax credits expected to be realized from Bison that will be credited to Minnesota Power’s retail customers through future renewable cost recovery rider filings as the tax credits are utilized.
[7]	The conservation improvement program regulatory liability represents CIP expenditures, any financial incentive earned for cost-effective program achievements and a carrying charge deferred for future refund over the next year following MPUC approval.
[8]	In 2018, Minnesota Power retired Boswell Units 1 and 2 and reclassified the remaining net book value from property, plant and equipment to a regulatory asset on the Consolidated Balance Sheet. The remaining net book value is currently included in Minnesota Power’s rate base and Minnesota Power is earning a return on the outstanding balance.
[9]	Fuel adjustment clause regulatory asset and liability represent the amount expected to be recovered from or refunded to customers for the under- or over-collection of fuel adjustment clause recoveries. (See Fuel Adjustment Clause.)
[10]	Asset retirement obligations will accrete and be amortized over the lives of the related property with asset retirement obligations.
[11]	The manufactured gas plant regulatory asset represents costs of remediation for a former manufactured gas plant site located in Superior, Wisconsin, and formerly operated by SWL&P. We expect recovery of these remediation costs to be allowed by the PSCW in rates over time.
[12]	The cost recovery rider regulatory assets and liabilities are revenue not yet collected from our customers and cash collections from our customers in excess of the revenue recognized, respectively, primarily due to capital expenditures related to Bison, the Boswell Unit 4 environmental upgrade and the GNTL as well as differences between production tax credits recognized and those assumed in Minnesota Power’s base rates. The cost recovery rider regulatory assets as of December 31, 2021, will be recovered within the next two years.

Operations and Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2021
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Financial Statement Preparation [Policy Text Block]	References in this report to “we,” “us,” and “our” are to ALLETE and its subsidiaries, collectively. We prepare our financial statements in conformity with GAAP. These principles require management to make informed judgments, best estimates, and assumptions that affect the reported amounts of assets, liabilities, revenue and expenses. Actual results could differ from those estimates.
Subsequent Events [Policy Text Block]	The Company performed an evaluation of subsequent events for potential recognition and disclosure through the time of the financial statements issuance.
Principles of Consolidation [Policy Text Block]	Our Consolidated Financial Statements include the accounts of ALLETE, all of our majority‑owned subsidiary companies and variable interest entities of which ALLETE is the primary beneficiary. All material intercompany balances and transactions have been eliminated in consolidation.
Variable Interest Entities [Policy Text Block]	The accounting guidance for “Variable Interest Entities” (VIE) is a consolidation model that considers if a company has a variable interest in a VIE. A VIE is a legal entity that possesses any of the following conditions: the entity’s equity at risk is not sufficient to permit the legal entity to finance its activities without additional subordinated financial support, equity owners are unable to direct the activities that most significantly impact the legal entity’s economic performance (or they possess disproportionate voting rights in relation to the economic interest in the legal entity), or the equity owners lack the obligation to absorb the legal entity’s expected losses or the right to receive the legal entity’s expected residual returns. Entities are required to consolidate a VIE when it is determined that they have a controlling financial interest in a VIE and therefore, are the primary beneficiary of that VIE, as defined by the accounting guidance for “Variable Interest Entities.” In determining whether ALLETE is the primary beneficiary of a VIE, management considers whether ALLETE has the power to direct the most significant activities of the VIE and is obligated to absorb losses or receive the expected residual returns that are significant to the VIE. The accounting guidance for VIEs applies to certain ALLETE Clean Energy wind energy facilities and our investment in Nobles 2. (See Tax Equity Financing.)
Business Segments [Policy Text Block]	We present three reportable segments: Regulated Operations, ALLETE Clean Energy and U.S. Water Services. Our segments were determined in accordance with the guidance on segment reporting. We measure performance of our operations through budgeting and monitoring of contributions to consolidated net income by each business segment. We present three reportable segments: Regulated Operations, ALLETE Clean Energy, and U.S. Water Services. We measure performance of our operations through budgeting and monitoring of contributions to consolidated net income by each business segment.
Cash and Cash Equivalents [Policy Text Block]	We consider all investments purchased with original maturities of three months or less to be cash equivalents.
Accounts Receivable [Policy Text Block]	Accounts receivable are reported on the Consolidated Balance Sheet net of an allowance for doubtful accounts. The allowance is based on our evaluation of the receivable portfolio under current conditions, overall portfolio quality, review of specific situations and such other factors that, in our judgment, deserve recognition in estimating losses.
Long-Term Finance Receivables [Policy Text Block]	Long-term finance receivables relating to our real estate operations are collateralized by property sold, accrue interest at market-based rates and are net of an allowance for doubtful accounts. We assess delinquent finance receivables by comparing the balance of such receivables to the estimated fair value of the collateralized property. If the fair value of the property is less than the finance receivable, we record a reserve for the difference. We estimate fair value based on recent property tax assessed values or current appraisals.
Available-for-Sale Securities [Policy Text Block]	Available-for-sale debt and equity securities are recorded at fair value. Unrealized gains and losses on available-for-sale debt securities are included in accumulated other comprehensive income (loss), net of tax. Unrealized gains and losses on available-for-sale equity securities are recognized in earnings. We use the specific identification method as the basis for determining the cost of securities sold.
Inventories [Policy Text Block]	Inventories are stated at the lower of cost or net realizable value. Inventories in our Regulated Operations segment are carried at an average cost or first-in, first-out basis. Inventories in our ALLETE Clean Energy segment and Corporate and Other businesses are carried at an average cost, first-in, first-out or specific identification basis.NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)
Property, Plant and Equipment [Policy Text Block]	Property, plant and equipment are recorded at original cost and are reported on the Consolidated Balance Sheet net of accumulated depreciation. Expenditures for additions, significant replacements, improvements and major plant overhauls are capitalized; maintenance and repair costs are expensed as incurred. Gains or losses on property, plant and equipment for Corporate and Other operations are recognized when they are retired or otherwise disposed. When property, plant and equipment in our Regulated Operations and ALLETE Clean Energy segments are retired or otherwise disposed, no gain or loss is recognized in accordance with the accounting standards for component depreciation except for certain circumstances where the retirement is unforeseen or unexpected. Our Regulated Operations capitalize AFUDC, which includes both an interest and equity component. AFUDC represents the cost of both debt and equity funds used to finance utility plant additions during construction periods. AFUDC amounts capitalized are included in rate base and are recovered from customers as the related property is depreciated. Upon MPUC approval of cost recovery, the recognition of AFUDC ceases. (See Note 2. Property, Plant and Equipment.)We believe that long-standing ratemaking practices approved by applicable state and federal regulatory commissions allow for the recovery of the remaining book value of retired plant assets. Minnesota Power’s 2015 IRP contained steps in Minnesota Power’s EnergyForward plan including the economic idling of Taconite Harbor Units 1 and 2 in 2016, and the ceasing of coal-fired operations at Taconite Harbor in 2020. As of December 31, 2021, Taconite Harbor had a net book value of approximately $45 million. The MPUC order for the 2015 IRP also directed Minnesota Power to retire Boswell Units 1 and 2, which occurred in the fourth quarter of 2018. As part of the 2016 general retail rate case, the MPUC allowed recovery of the remaining book value of Boswell Units 1 and 2 through 2022. In its latest IRP filing, Minnesota Power proposed retiring Boswell Unit 3 by 2030 and transforming Boswell Unit 4 to be coal-free by 2035. Boswell Unit 3 and Unit 4 have a net book value of approximately $245 million and $435 million, respectively, as of December 31, 2021. (See Note 4. Regulatory Matters.) We do not expect to record any impairment charge as a result of these operating changes at Taconite Harbor and Boswell. In addition, we expect to be able to continue depreciating these assets for at least their established remaining useful lives; however, we are unable to predict the impact of regulatory outcomes resulting in changes to their established remaining useful lives.
Impairment of Long-Lived Assets [Policy Text Block]	We review our long-lived assets for indicators of impairment in accordance with the accounting standards for property, plant and equipment on a quarterly basis. This includes our property, plant and equipment (see Property, Plant and Equipment) and land inventory. Land inventory is accounted for as held for use and is recorded at cost, unless the carrying value is determined not to be recoverable in accordance with the accounting standards for property, plant and equipment, in which case the land inventory is written down to estimated fair value.In accordance with the accounting standards for property, plant and equipment, if indicators of impairment exist, we test our long‑lived assets for recoverability by comparing the carrying amount of the asset to the undiscounted future net cash flows expected to be generated by the asset. Cash flows are assessed at the lowest level of identifiable cash flows. The undiscounted future net cash flows are impacted by trends and factors known to us at the time they are calculated and our expectations related to: management’s best estimate of future use; sales prices; holding period and timing of sales; method of disposition; and future expenditures necessary to maintain the operations.
Derivatives [Policy Text Block]	ALLETE is exposed to certain risks relating to its business operations that can be managed through the use of derivative instruments. ALLETE may enter into derivative instruments to manage those risks including interest rate risk related to certain variable-rate borrowings and commodity price risk related to sales to retail and municipal customers as well as other power suppliers. We have determined that either these agreements are not derivatives, or, if they are derivatives, the agreements qualify for the normal purchases and normal sales exception to derivative accounting guidance; therefore, derivative accounting is not required.
Accounting for Stock-Based Compensation [Policy Text Block]	We apply the fair value recognition guidance for share-based payments. Under this guidance, we recognize stock-based compensation expense for all share-based payments granted, net of an estimated forfeiture rate. (See Note 12. Employee Stock and Incentive Plans.) Performance Shares. Under the performance share awards, the number of shares earned is contingent upon attaining specific market and performance goals over a three-year performance period. Market goals are measured by total shareholder return relative to a group of peer companies while performance goals are measured by earnings per share growth. In the case of qualified retirement, death, or disability during a performance period, a pro rata portion of the award will be earned at the conclusion of the performance period based on the market goals achieved. In the case of termination of employment for any reason other than qualified retirement, death, or disability, no award will be earned. If there is a change in control, a pro rata portion of the award will be paid based on the greater of actual performance up to the date of the change in control or target performance. The fair value of these awards incorporates the probability of meeting the total shareholder return goals. Compensation cost is recognized over the three-year performance period based on our estimate of the number of shares which will be earned by the award recipients. Restricted Stock Units. Under the restricted stock unit awards, shares for participants eligible for retirement vest monthly over a three-year period. For participants not eligible for retirement, shares vest at the end of the three-year period. In the case of qualified retirement, death or disability, a pro rata portion of the award will be earned. In the case of termination of employment for any reason other than qualified retirement, death or disability, no award will be earned. If there is a change in control, a pro rata portion of the award will be earned. The fair value of these awards is equal to the grant date fair value. Compensation cost is recognized over the three-year vesting period based on our estimate of the number of shares which will be earned by the award recipients. Employee Stock Purchase Plan (ESPP). Under our ESPP, eligible employees may purchase ALLETE common stock at a 5 percent discount from the market price; we are not required to apply fair value accounting to these awards as the discount is not greater than 5 percent. RSOP. The RSOP is a contributory defined contribution plan subject to the provisions of the Employee Retirement Income Security Act of 1974, as amended, and qualifies as an employee stock ownership plan and profit sharing plan. The RSOP provides eligible employees an opportunity to save for retirement.
Short-term Leases [Policy Text Block]	Lease and rent expense is recognized on a straight-line basis over the lease term. Leases with a term of 12 months or less are not recognized on the Consolidated Balance Sheet.
Environmental Liabilities [Policy Text Block]	We review environmental matters on a quarterly basis. Accruals for environmental matters are recorded when it is probable that a liability has been incurred and the amount of the liability can be reasonably estimated based on current law and existing technologies. Accruals are adjusted as assessment and remediation efforts progress, or as additional technical or legal information becomes available. Accruals for environmental liabilities are included in the Consolidated Balance Sheet at undiscounted amounts and exclude claims for recoveries from insurance or other third parties. Costs related to environmental contamination treatment and cleanup are expensed unless recoverable in rates from customers.We review environmental matters on a quarterly basis. Accruals for environmental matters are recorded when it is probable that a liability has been incurred and the amount of the liability can be reasonably estimated based on current law and existing technologies. Accruals are adjusted as assessment and remediation efforts progress, or as additional technical or legal information becomes available. Accruals for environmental liabilities are included in the Consolidated Balance Sheet at undiscounted amounts and exclude claims for recoveries from insurance or other third parties. Costs related to environmental contamination treatment and cleanup are expensed unless recoverable in rates from customers.
Leases [Policy Text Block]	We determine if a contract is, or contains, a lease at inception and recognize a right-of-use asset and lease liability for all leases with a term greater than 12 months. Our right-of-use assets and lease liabilities for operating leases are included in Other Non-Current Assets, Other Current Liabilities and Other Non-Current Liabilities, respectively, in our Consolidated Balance Sheet. We currently do not have any finance leases. Right-of-use assets represent our right to use an underlying asset for the lease term and lease liabilities represent the obligation to make lease payments arising from the lease. Operating lease right-of-use assets and lease liabilities are recognized at the commencement date based on the estimated present value of lease payments over the lease term. As our leases do not provide an explicit rate, we determine the present value of future lease payments based on our estimated incremental borrowing rate using information available at the lease commencement date. The operating lease right-of-use asset includes lease payments to be made during the lease term and any lease incentives, as applicable. Our leases may include options to extend or buy out the lease at certain points throughout the term, and if it is reasonably certain at lease commencement that we will exercise that option, we include those rental payments in our calculation of the right-of-use asset and lease liability. Lease and rent expense is recognized on a straight-line basis over the lease term. Leases with a term of 12 months or less are not recognized on the Consolidated Balance Sheet. The majority of our operating leases are for heavy equipment, vehicles and land with fixed monthly payments which we group into two categories: Vehicles and Equipment; and Land and Other. Our largest operating lease is for the dragline at BNI Energy which includes a termination payment at the end of the lease term if we do not exercise our purchase option. The amount of this payment is $3 million and is included in our calculation of the right-of-use asset and lease liability recorded. None of our other leases contain residual value guarantees.
Revenue Recognition [Policy Text Block]	Revenue is recognized upon transfer of control of promised goods or services to our customers in an amount that reflects the consideration we expect to receive in exchange for those products or services. Revenue is recognized net of allowance for returns and any taxes collected from customers, which are subsequently remitted to the appropriate governmental authorities. We account for shipping and handling activities that occur after the customer obtains control of goods as a cost rather than an additional performance obligation thereby recognizing revenue at time of shipment and accruing shipping and handling costs when control transfers to our customers. We have a right to consideration from our customers in an amount that corresponds directly with the value to the customer for our performance completed to date; therefore, we may recognize revenue in the amount to which we have a right to invoice. NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued) Revenue (Continued) Nature of Revenue Streams Utility Residential and Commercial includes sales for electric, gas or water service to customers, who have implied contracts with the utility, under rates governed by the MPUC, PSCW or FERC. Customers are billed on a monthly cycle basis and revenue is recognized for electric, gas or water service delivered during the billing period. Revenue is accrued for service provided but not yet billed at period end. Performance obligations with these customers are satisfied at time of delivery to customer meters and simultaneously consumed. Municipal includes sales to 15 non-affiliated municipal customers in Minnesota under long-term wholesale electric contracts. All wholesale electric contracts include a termination clause requiring a three-year notice to terminate. These contracts have termination dates ranging through 2037, with a majority of contracts effective through 2029. Performance obligations with these customers are satisfied at the time energy is delivered to an agreed upon municipal substation or meter. Industrial includes sales recognized from contracts with customers in the taconite mining, paper, pulp and secondary wood products, pipeline and other industries. Industrial sales accounted for approximately 47 percent of total regulated utility kWh sales for the year ended December 31, 2021. Within industrial revenue, Minnesota Power had eight Large Power Customer contracts, each serving requirements of 10 MW or more of customer load as of December 31, 2021. These contracts automatically renew past the contract term unless a four-year advanced written notice is given. Large Power Customer contracts have earliest termination dates ranging from 2025 through 2029. In January 2021, Verso Corporation provided notice of termination for its contract. Minnesota Power and Verso Corporation mutually agreed to resolve the outstanding commitments under the contract in January 2022. We satisfy our performance obligations for these customers at the time energy is delivered to an agreed upon customer substation. Revenue is accrued for energy provided but not yet billed at period end. Based on current contracts with industrial customers, we expect to recognize minimum revenue for the fixed contract components of approximately $50 million per annum through 2025, $15 million in 2026, and $30 million in total thereafter, which reflects the termination notice period in these contracts. When determining minimum revenue, we assume that customer contracts will continue under the contract renewal provision; however, if long-term contracts are renegotiated and subsequently approved by the MPUC or there are changes within our industrial customer class, these amounts may be impacted. Contracts with customers that contain variable pricing or quantity components are excluded from the expected minimum revenue amounts. Other Power Suppliers includes the sale of energy under a long-term PSA with one customer as well as MISO market and liquidation sales. The expiration date of this PSA is 2028. Performance obligations with these customers are satisfied at the time energy is delivered to an agreed upon delivery point defined in the contract (generally the MISO pricing node). The current contract with one customer contains variable pricing components that prevent us from estimating future minimum revenue. Other Revenue includes all remaining individually immaterial revenue streams for Minnesota Power and SWL&P, and is comprised of steam sales to paper and pulp mills, wheeling revenue and other sources. Revenue for steam sales to customers is recognized at the time steam is delivered and simultaneously consumed. Revenue is recognized at the time each performance obligation is satisfied. CIP Financial Incentive reflects certain revenue that is a result of the achievement of certain objectives for our CIP financial incentives. This revenue is accounted for in accordance with the accounting standards for alternative revenue programs which allow for the recognition of revenue under an alternative revenue program if the program is established by an order from the utility’s regulatory commission, the order allows for automatic adjustment of future rates, the amount of revenue recognized is objectively determinable and probable of recovery, and the revenue will be collected within 24 months following the end of the annual period in which it is recognized. CIP financial incentives are recognized in the period in which the MPUC approves the filing, which is typically mid-year. NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued) Revenue (Continued) Non-utility ALLETE Clean Energy Long-term PSA revenue includes all sales recognized under long-term contracts for production, curtailment, capacity and associated renewable energy credits from ALLETE Clean Energy wind energy facilities. Expiration dates of these PSAs range from 2022 through 2039. Performance obligations for these contracts are satisfied at the time energy is delivered to an agreed upon point, or production is curtailed at the request of the customer, at specified prices. Revenue from the sale of renewable energy credits is recognized at the same time the related energy is delivered to the customer when sold to the same party. Sale of Wind Energy Facility includes revenue recognized for the design, development, construction, and sale of a wind energy facility to a customer. Performance obligations for these types of agreements are satisfied at the time the completed project is transferred to the customer at the commercial operation date. Revenue from the sale of a wind energy facility is recognized at the time of asset transfer. Other is the non-cash adjustments to revenue recognized by ALLETE Clean Energy for the amortization of differences between contract prices and estimated market prices on assumed PSAs. As part of wind energy facility acquisitions, ALLETE Clean Energy assumed various PSAs that were above or below estimated market prices at the time of acquisition; the resulting differences between contract prices and estimated market prices are amortized to revenue over the remaining PSA term. U.S. Water Services In 2019, ALLETE completed the sale of U.S. Water Services. Prior to the sale, ALLETE recognized revenue under the point-in-time, contract and capital project streams. Point-in-time revenue was recognized for purchases by customers for chemicals, consumable equipment or related maintenance and repair services as the customer’s usage and needs changed over time. Contract revenue included monthly revenue from contracts with customers to provide chemicals, consumable equipment and services to meet customer needs during the contract period at a fixed monthly price. Capital Project revenue was recognized at the time of sale when equipment and other components were assembled to create a water treatment system for a customer. Corporate and Other Long-term Contract encompasses the sale and delivery of coal to customer generation facilities. Revenue is recognized on a monthly basis at the cost of production plus a specified profit per ton of coal delivered to the customer. Coal sales are secured under long-term coal supply agreements extending through 2037. Performance obligations are satisfied during the period as coal is delivered to customer generation facilities. Other primarily includes revenue from BNI Energy unrelated to coal, the sale of real estate from ALLETE Properties, and non‑rate base steam generation that is sold for use during production of paper and pulp. Performance obligations are satisfied when control transfers to the customer. Payment Terms Payment terms and conditions vary across our businesses. Aside from taconite-producing Large Power Customers, payment terms generally require payment to be made within 15 to 30 days from the end of the period that the service has been rendered. In the case of its taconite-producing Large Power Customers, as permitted by the MPUC, Minnesota Power requires weekly payments for electric usage based on monthly energy usage estimates. These customers receive estimated bills based on Minnesota Power’s estimate of the customers’ energy usage, forecasted energy prices and fuel adjustment clause estimates. Minnesota Power’s taconite-producing Large Power Customers have generally predictable energy usage on a weekly basis and any differences that occur are trued-up the following month. Due to the timing difference of revenue recognition from the timing of invoicing and payment, the taconite-producing Large Power Customers receive credit for the time value of money; however, we have determined that our contracts do not include a significant financing component as the period between when we transfer the service to the customer and when they pay for such service is minimal. NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued) Revenue (Continued) Assets Recognized From the Costs to Obtain a Contract with a Customer We recognize as an asset the incremental costs of obtaining a contract with a customer if we expect the benefit of those costs to be longer than one year. We expense incremental costs when the asset that would have resulted from capitalizing these costs would have been amortized in one year or less. As of December 31, 2021, we have $23.3 million of assets recognized for costs incurred to obtain contracts with our customers ($25.5 million as of December 31, 2020). Management determined the amount of costs to be recognized as assets based on actual costs incurred and paid to obtain and fulfill these contracts to provide goods and services to our customers. Assets recognized to obtain contracts are amortized on a straight-line basis over the contract term as a non-cash reduction to revenue. We recognized $2.7 million of non-cash amortization for the year ended December 31, 2021 ($2.6 million for the year end December 31, 2020).
Revenue from CIP Financial Incentive [Policy Text Block]	reflects certain revenue that is a result of the achievement of certain objectives for our CIP financial incentives. This revenue is accounted for in accordance with the accounting standards for alternative revenue programs which allow for the recognition of revenue under an alternative revenue program if the program is established by an order from the utility’s regulatory commission, the order allows for automatic adjustment of future rates, the amount of revenue recognized is objectively determinable and probable of recovery, and the revenue will be collected within 24 months following the end of the annual period in which it is recognized. CIP financial incentives are recognized in the period in which the MPUC approves the filing, which is typically mid-year.
Unamortized Discount and Premium on Debt [Policy Text Block]	Discount and premium on debt are deferred and amortized over the terms of the related debt instruments using a method which approximates the effective interest method.
Non-Controlling Interest in Subsidiaries [Policy Text Block]	For those wind projects with tax equity financings where the economic benefits are not allocated based on the underlying ownership percentage interests, we have determined that the appropriate methodology for calculating the non-controlling interest in subsidiaries balance is the hypothetical liquidation at book value (HLBV) method. The HLBV method is a balance sheet approach which reflects the substantive economic arrangements in the tax equity financing structures. NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued) Non-Controlling Interest in Subsidiaries (Continued) Under the HLBV method, amounts reported as non-controlling interest in subsidiaries on the Consolidated Balance Sheet represent the amounts the third-party investors would hypothetically receive at each balance sheet reporting date under the liquidation provisions of the LLC agreements, assuming the net assets of the wind projects were liquidated at amounts determined in accordance with GAAP and distributed to the third-party investor and sponsor. The resulting non-controlling interest in subsidiaries balance in these projects is reported as a component of equity on the Consolidated Balance Sheet. The results of operations for these projects attributable to non-controlling interest under the HLBV method is determined as the difference in non-controlling interest in subsidiaries on the Consolidated Balance Sheet at the start and end of each reporting period, after taking into account any capital transactions between the projects and the third-party investors. Factors used in the HLBV calculation include GAAP income, taxable income (loss), tax attributes such as accelerated depreciation and production tax credits, capital contributions, cash distributions, and the target yield specified in the corresponding LLC agreement. Changes in these factors could have a significant impact on the amounts that third-party investors and sponsors would receive upon a hypothetical liquidation. The use of the HLBV method to allocate income to the non-controlling interest in subsidiaries may create variability in our results of operations as the application of the HLBV method can drive variability in net income or loss attributable to non-controlling interest in subsidiaries from period to period.
Income Taxes [Policy Text Block]	ALLETE and its subsidiaries file a consolidated federal income tax return as well as combined and separate state income tax returns. We account for income taxes using the liability method in accordance with GAAP for income taxes. Under the liability method, deferred income tax assets and liabilities are established for all temporary differences in the book and tax basis of assets and liabilities, based upon enacted tax laws and rates applicable to the periods in which the taxes become payable. We account for the collection and payment of these taxes on a net basis.We have established a valuation allowance against certain state NOL and tax credits that we do not expect to utilize before their expiration.
Unrecognized Tax Benefits [Policy Text Block]	Unrecognized tax benefits are the differences between a tax position taken or expected to be taken in a tax return and the benefit recognized and measured pursuant to the “more-likely-than-not” criteria. The unrecognized tax benefit balance includes permanent tax positions which, if recognized would affect the annual effective income tax rate. In addition, the unrecognized tax benefit balance includes temporary tax positions for which the ultimate deductibility is highly certain but for which there is uncertainty about the timing of such deductibility. A change in the period of deductibility would not affect the effective tax rate but would accelerate the payment of cash to the taxing authority to an earlier period.We classify interest related to unrecognized tax benefits as interest expense and tax-related penalties in operating expenses on the Consolidated Statement of Income.The unrecognized tax benefit amounts have been presented as reductions to the tax benefits associated with NOL and tax credit carryforwards on the Consolidated Balance Sheet.
Excise Taxes [Policy Text Block]	We collect excise taxes from our customers levied by governmental entities. These taxes are stated separately on the billing to the customer and recorded as a liability to be remitted to the governmental entity. We account for the collection and payment of these taxes on a net basis.
Depreciation [Policy Text Block]	Depreciation is computed using the straight-line method over the estimated useful lives of the various classes of assets.
Asset Retirement Obligations [Policy Text Block]	We recognize, at fair value, obligations associated with the retirement of certain tangible, long‑lived assets that result from the acquisition, construction, development or normal operation of the asset. Asset retirement obligations (AROs) relate primarily to the decommissioning of our coal-fired and wind energy facilities, and land reclamation at BNI Energy. AROs are included in Other Non-Current Liabilities on the Consolidated Balance Sheet. The associated retirement costs are capitalized as part of the related long-lived asset and depreciated over the useful life of the asset. Removal costs associated with certain distribution and transmission assets have not been recognized, as these facilities have indeterminate useful lives. Conditional asset retirement obligations have been identified for treated wood poles and remaining polychlorinated biphenyl and asbestos-containing assets; however, the period of remediation is indeterminable and removal liabilities have not been recognized.Long-standing ratemaking practices approved by applicable state and federal regulatory authorities have allowed provisions for future plant removal costs in depreciation rates. These plant removal cost recoveries are classified either as AROs or as a regulatory liability for non-AROs. To the extent annual accruals for plant removal costs differ from accruals under approved depreciation rates, a regulatory asset has been established in accordance with GAAP for AROs.
Regulatory Assets and Liabilities [Policy Text Block]	Our regulated utility operations are subject to accounting standards for the effects of certain types of regulation. Regulatory assets represent incurred costs that have been deferred as they are probable for recovery in customer rates. Regulatory liabilities represent obligations to make refunds to customers and amounts collected in rates for which the related costs have not yet been incurred. The Company assesses quarterly whether regulatory assets and liabilities meet the criteria for probability of future recovery or deferral. With the exception of the regulatory asset for Boswell Units 1 and 2 net plant and equipment, no other regulatory assets are currently earning a return. The recovery, refund or credit to rates for these regulatory assets and liabilities will occur over the periods either specified by the applicable regulatory authority or over the corresponding period related to the asset or liability.
Equity Method Investments [Policy Text Block]	We account for our investment in ATC under the equity method of accounting.We account for our investment in Nobles 2 under the equity method of accounting.The Company assesses our equity investments in ATC and Nobles 2 for impairment whenever events or changes in circumstances indicate that the carrying amount of our investments may not be recoverable.
Fair Value Measurement [Policy Text Block]	We utilize market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated, or generally unobservable. We primarily apply the market approach for recurring fair value measurements and endeavor to utilize the best available information. Accordingly, we utilize valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. These inputs, which are used to measure fair value, are prioritized through the fair value hierarchy.Each asset and liability is classified based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment, which may affect the valuation of these assets and liabilities and their placement within the fair value hierarchy levels. The estimated fair value of Cash and Cash Equivalents listed on the Consolidated Balance Sheet approximates the carrying amount and therefore is excluded from the recurring fair value measures in the following tables.Non-financial assets such as equity method investments, goodwill, intangible assets, and property, plant and equipment are measured at fair value when there is an indicator of impairment and recorded at fair value only when an impairment is recognized.Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). We utilize market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated, or generally unobservable. We primarily apply the market approach for recurring fair value measurements and endeavor to utilize the best available information. Accordingly, we utilize valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. These inputs, which are used to measure fair value, are prioritized through the fair value hierarchy. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). (See Note 6. Fair Value.)
Fair Value Transfers [Policy Text Block]	The Company’s policy is to recognize transfers in and transfers out of Levels as of the actual date of the event or change in circumstances that caused the transfer.
Property, Plant and Equipment Impairment [Policy Text Block]	The Company assesses the impairment of property, plant, and equipment whenever events or changes in circumstances indicate that the carrying amount of property, plant, and equipment assets may not be recoverable.
Pension and Other Postretirement Benefit Plans [Policy Text Block]	Management considers various factors when making funding decisions such as regulatory requirements, actuarially determined minimum contribution requirements and contributions required to avoid benefit restrictions for the pension plans. Contributions are based on estimates and assumptions which are subject to change Accounting for defined benefit pension and other postretirement benefit plans requires that employers recognize on a prospective basis the funded status of their defined benefit pension and other postretirement plans on their balance sheet and recognize as a component of other comprehensive income, net of tax, the gains or losses and prior service costs or credits that arise during the period but are not recognized as components of net periodic benefit cost. The defined benefit pension and postretirement health and life benefit expense (credit) recognized annually by our regulated utilities are expected to be recovered (refunded) through rates filed with our regulatory jurisdictions. As a result, these amounts that are required to otherwise be recognized in accumulated other comprehensive income have been recognized as a long-term regulatory asset (regulatory liability) on the Consolidated Balance Sheet, in accordance with the accounting standards for the effect of certain types of regulation applicable to our Regulated Operations. The defined benefit pension and postretirement health and life benefit expense (credits) associated with our other operations are recognized in accumulated other comprehensive income. NOTE 11. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS (Continued)According to the accounting standards for retirement benefits, only assets in the VEBAs are treated as plan assets in the preceding table for the purpose of determining funded status. In establishing the expected long-term rate of return on plan assets, we determine the long-term historical performance of each asset class, adjust these for current economic conditions, and utilizing the target allocation of our plan assets, forecast the expected long-term rate of return. The discount rate is computed using a bond matching study which utilizes a portfolio of high quality bonds that produce cash flows similar to the projected costs of our pension and other postretirement plans. The Company utilizes actuarial assumptions about mortality to calculate the pension and postretirement health and life benefit obligations.
Employee Stock Ownership Plan [Policy Text Block]	The dividends received by the ESOP are distributed to participants. Dividends on allocated ESOP shares are recorded as a reduction of retained earnings. ESOP employer allocations are funded with contributions paid in either cash or the issuance of ALLETE common stock at the Company’s discretion.According to the accounting standards for stock compensation, unallocated shares of ALLETE common stock held and purchased by the ESOP were treated as unearned ESOP shares and not considered outstanding for earnings per share computations. All ESOP shares have been allocated to participants as of December 31, 2021, 2020 and 2019.

Consolidated Statement of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating Activities
Net Income	$ 137.8	$ 161.6	$ 185.5
AFUDC – Equity	(2.6)	(1.9)	(2.3)
Income from Equity Investments – Net of Dividends	2.2	(3.2)	(5.6)
Gain on Investments and Property, Plant and Equipment	(0.8)	(1.3)	(1.6)
Depreciation Expense	231.6	217.7	200.6
Amortization of PSAs	(11.4)	(11.3)	(11.6)
Amortization of Other Intangible Assets and Other Assets	9.9	10.4	11.7
Deferred Income Tax Benefit	(26.9)	(39.5)	(6.7)
Share-Based and ESOP Compensation Expense	5.9	6.1	6.3
Defined Benefit Pension and Other Postretirement Benefit Expense	4.3	0.1	1.2
Bad Debt Expense	1.2	2.7	(0.1)
Provision (Payments) for Interim Rate Refund	0.0	0.0	(40.0)
Provision (Payments) for Tax Reform Refund	0.0	(0.2)	(10.4)
Gain on Sale of U.S. Water Services	0.0	0.0	(23.6)
Changes in Operating Assets and Liabilities
Accounts Receivable	(13.0)	(18.2)	22.6
Inventories	(23.5)	(1.4)	(4.1)
Prepayments and Other	(0.5)	0.9	0.3
Accounts Payable	15.0	11.8	(8.8)
Other Current Liabilities	28.0	11.7	(13.7)
Cash Contributions to Defined Benefit Pension Plans	(10.3)	(10.7)	(10.4)
Changes in Fuel Adjustment Clause Regulatory Asset and Liability	(56.4)	5.0	0.0
Changes in Regulatory and Other Non-Current Assets	(12.0)	(31.0)	(25.2)
Changes in Regulatory and Other Non-Current Liabilities	(15.0)	(9.5)	(17.2)
Cash from Operating Activities	263.5	299.8	246.9
Investing Activities
Proceeds from Sale of Available-for-sale Securities	6.4	12.8	12.1
Payments for Purchase of Available-for-sale Securities	(3.6)	(8.7)	(12.2)
Payments for Equity Investments	(17.6)	(99.1)	(37.9)
Return of Capital from Equity Investments	0.0	0.0	8.3
Additions to Property, Plant and Equipment	(473.3)	(717.8)	(597.1)
Proceeds from Sale of U.S. Water Services - Net of Transaction Costs and Cash Retained	0.0	0.0	268.6
Other Investing Activities	2.9	0.0	15.5
Cash for Investing Activities	(485.2)	(812.8)	(342.7)
Financing Activities
Proceeds from Issuance of Common Stock	69.9	18.1	1.9
Proceeds from Issuance of Long-Term Debt	733.0	672.4	201.9
Repayments of Short-Term and Long-Term Debt	(552.9)	(488.6)	(72.2)
Proceeds from Non-Controlling Interest in Subsidiaries - Net of Issuance Costs	90.9	414.5	103.8
Acquisition-Related Contingent Consideration Payments	0.0	0.0	(3.8)
Dividends on Common Stock	(131.9)	(128.2)	(121.4)
Other Financing Activities	(4.8)	(2.5)	(0.9)
Cash (for) from Financing Activities	204.2	485.7	109.3
Change in Cash, Cash Equivalents and Restricted Cash	(17.5)	(27.3)	13.5
Cash, Cash Equivalents and Restricted Cash	$ 47.7	$ 65.2	$ 92.5

Commitments, Guarantees and Contingencies

12 Months Ended

Dec. 31, 2021

Commitments, Guarantees and Contingencies [Text Block]

COMMITMENTS, GUARANTEES AND CONTINGENCIES

The following table details the estimated minimum payments for certain long-term commitments:


As of December 31, 2021
Millions	2022	2023	2024	2025	2026	Thereafter

Capital Purchase Obligations	$50.7	$0.1	—	—	—	—
Easements (a)	$8.2	$8.4	$8.4	$8.8	$9.2	$239.7
PPAs (b)	$141.1	$140.7	$133.5	$131.4	$138.3	$1,060.6
Other Purchase Obligations (c)	$58.9	$22.5	$23.1	—	—	—

(a)Easement obligations represent the minimum payments for our land easement agreements at our wind energy facilities.

(c)Consists of long-term service agreements for wind energy facilities and minimum purchase commitments under coal and rail contracts.

Power Purchase and Sales Agreements. Our long-term PPAs have been evaluated under the accounting guidance for variable interest entities. We have determined that either we have no variable interest in the PPAs, or where we do have variable interests, we are not the primary beneficiary; therefore, consolidation is not required. These conclusions are based on the fact that we do not have both control over activities that are most significant to the entity and an obligation to absorb losses or receive benefits from the entity’s performance. Our financial exposure relating to these PPAs is limited to our capacity and energy payments.

These agreements have also been evaluated under the accounting guidance for derivatives. We have determined that either these agreements are not derivatives, or, if they are derivatives, the agreements qualify for the normal purchases and normal sales exception to derivative accounting guidance; therefore, derivative accounting is not required.

Square Butte PPA. Minnesota Power has a PPA with Square Butte that extends through 2026 (Agreement). Minnesota Power is obligated to pay its pro rata share of Square Butte’s costs based on its entitlement to the output of Square Butte’s 455 MW coal‑fired generating unit. Minnesota Power’s output entitlement under the Agreement is 50 percent for the remainder of the Agreement, subject to the provisions of the Minnkota Power PSA described in the following table. Minnesota Power’s payment obligation will be suspended if Square Butte fails to deliver any power, whether produced or purchased, for a period of one year. Square Butte’s costs consist primarily of debt service, operating and maintenance, depreciation and fuel expenses. As of December 31, 2021, Square Butte had total debt outstanding of $222.6 million. Annual debt service for Square Butte is expected to be approximately $45.5 million annually through 2023, $30.5 million in 2024, $26.6 million in 2025, and $40.1 million in 2026, of which Minnesota Power’s obligation is 50 percent. Fuel expenses are recoverable through Minnesota Power’s fuel adjustment clause and include the cost of coal purchased from BNI Energy under a long-term contract.

NOTE 8. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)

Power Purchase and Sales Agreements (Continued)

Minnesota Power’s cost of power purchased from Square Butte during 2021 was $82.4 million ($79.5 million in 2020; $82.7 million in 2019). This reflects Minnesota Power’s pro rata share of total Square Butte costs based on the 50 percent output entitlement. Included in this amount was Minnesota Power’s pro rata share of interest expense of $5.8 million in 2021 ($7.1 million in 2020; $8.3 million in 2019). Minnesota Power’s payments to Square Butte are approved as a purchased power expense for ratemaking purposes by both the MPUC and the FERC.

Minnesota Power has also entered into the following long-term PPAs for the purchase of capacity and energy as of December 31, 2021:

Counterparty

Quantity

Product

Commencement

Expiration

Pricing

PPAs

Calpine Corporation

25 MW

Capacity

June 2019

May 2026

Fixed

Manitoba Hydro

PPA 1

(a)

Energy

May 2011

April 2022

Forward Market Prices

PPA 2

250 MW

Capacity / Energy

June 2020

May 2035

(b)

PPA 3

133 MW

Energy

June 2020

June 2040

Forward Market Prices

Nobles 2

250 MW

Capacity / Energy

December 2020

December 2040

Fixed

Oliver Wind I

(c)

Energy

December 2006

December 2040

Fixed

Oliver Wind II

(c)

Energy

December 2007

December 2040

Fixed

(c)The PPAs provide for the purchase of all output from the 50 MW Oliver Wind I and 48 MW Oliver Wind II wind energy facilities.

Minnesota Power has also entered into the following long-term PSAs for the sale of capacity and energy as of December 31, 2021:

Counterparty

Quantity

Product

Commencement

Expiration

Pricing

PSAs

Basin

PSA 1

(a)

Capacity

June 2022

May 2025

Fixed

PSA 2

100 MW

Capacity

June 2025

May 2028

Fixed

Great River Energy

100 MW

Capacity

June 2022

May 2025

Fixed

Minnkota Power

(b)

Capacity / Energy

June 2014

December 2026

(b)

Oconto Electric Cooperative

25 MW

Capacity / Energy

January 2019

May 2026

Fixed

Silver Bay Power

(c)

Energy

January 2017

December 2031

(d)

(a)The agreement provides for 75 MW of capacity from June 1, 2022, through May 31, 2023, and increases to 125 MW of capacity from June 1, 2023, through May 31, 2025.

(d)The energy pricing escalates at a fixed rate annually and is adjusted for changes in a natural gas index.

Coal, Rail and Shipping Contracts. Minnesota Power has coal supply agreements providing for the purchase of a significant portion of its coal requirements through December 2022. Minnesota Power also has coal transportation agreements in place for the delivery of a significant portion of its coal requirements through December 2024. The costs of fuel and related transportation costs for Minnesota Power’s generation are recoverable from Minnesota Power’s utility customers through the fuel adjustment clause.

Environmental Matters.

Our businesses are subject to regulation of environmental matters by various federal, state and local authorities. A number of regulatory changes to the Clean Air Act, the Clean Water Act and various waste management requirements have been promulgated by both the EPA and state authorities over the past several years. Minnesota Power’s facilities are subject to additional requirements under many of these regulations. Minnesota Power is reshaping its generation portfolio, over time, to reduce its reliance on coal, has installed cost-effective emission control technology, and advocates for sound science and policy during rulemaking implementation.

We consider our businesses to be in substantial compliance with currently applicable environmental regulations and believe all necessary permits have been obtained. We anticipate that with many state and federal environmental regulations and requirements finalized, or to be finalized in the near future, potential expenditures for future environmental matters may be material and require significant capital investments. Minnesota Power has evaluated various environmental compliance scenarios using possible outcomes of environmental regulations to project power supply trends and impacts on customers.

We review environmental matters on a quarterly basis. Accruals for environmental matters are recorded when it is probable that a liability has been incurred and the amount of the liability can be reasonably estimated based on current law and existing technologies. Accruals are adjusted as assessment and remediation efforts progress, or as additional technical or legal information becomes available. Accruals for environmental liabilities are included in the Consolidated Balance Sheet at undiscounted amounts and exclude claims for recoveries from insurance or other third parties. Costs related to environmental contamination treatment and cleanup are expensed unless recoverable in rates from customers.

Air. The electric utility industry is regulated both at the federal and state level to address air emissions. Minnesota Power’s thermal generating facilities mainly burn low-sulfur western sub-bituminous coal. All of Minnesota Power’s coal-fired generating facilities are equipped with pollution control equipment such as scrubbers, baghouses and low NOX technologies. Under currently applicable environmental regulations, these facilities are substantially compliant with emission requirements.

Cross-State Air Pollution Rule (CSAPR). The CSAPR requires certain states in the eastern half of the U.S., including Minnesota, to reduce power plant emissions that contribute to ozone or fine particulate pollution in other states. The CSAPR does not require installation of controls but does require facilities have sufficient allowances to cover their emissions on an annual basis. These allowances are allocated to facilities from each state’s annual budget, and can be bought and sold. Based on our review of the NOX and SO2 allowances issued and pending issuance, we currently expect generation levels and emission rates will result in continued compliance with the CSAPR. The EPA’s CSAPR Update Rule issued on March 15, 2021, to revise the 2016 CSAPR Update does not apply to the state of Minnesota and is therefore not currently projected to affect Minnesota Power’s CSAPR compliance. The State of Minnesota has not been identified in litigation as a culpable upwind emission source to downwind states, and previous EPA air quality modeling has demonstrated that Minnesota is not a significant contributor to downwind air quality attainment challenges. Minnesota Power will continue to monitor ongoing CSAPR rulemakings and compliance implementation.

National Ambient Air Quality Standards (NAAQS). The EPA is required to review the NAAQS every five years. If the EPA determines that a state’s air quality is not in compliance with the NAAQS, the state is required to adopt plans describing how it will reduce emissions to attain the NAAQS. Minnesota Power actively monitors NAAQS developments and compliance costs for existing standards or proposed NAAQS revisions are not currently expected to be material. The EPA is currently reviewing the secondary NAAQS for NOx and SO2, as well as particulate matter. On June 10, 2021, the EPA announced it will reconsider the December 2020 final rule retaining the 2012 particulate matter NAAQS annual standard, with a proposed rulemaking anticipated in late 2022 and final action expected in early 2023. The EPA also stated it would complete reconsideration of the December 2020 Ozone NAAQS by the end of 2023.

NOTE 8. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)

Environmental Matters (Continued)

Climate Change. The scientific community generally accepts that emissions of GHG are linked to global climate change which creates physical and financial risks. Physical risks could include, but are not limited to: increased or decreased precipitation and water levels in lakes and rivers; increased or other changes in temperatures; and changes in the intensity and frequency of extreme weather events. These all have the potential to affect the Company’s business and operations. We are addressing climate change by taking the following steps that also ensure reliable and environmentally compliant generation resources to meet our customers’ requirements:

•Expanding renewable power supply for both our operations and the operations of others;

•Providing energy conservation initiatives for our customers and engaging in other demand side management efforts;

•Improving efficiency of our generating facilities;

•Supporting research of technologies to reduce carbon emissions from generating facilities and carbon sequestration efforts;

•Evaluating and developing less carbon intensive future generating assets such as efficient and flexible natural gas‑fired generating facilities;

•Managing vegetation on right-of-way corridors to reduce potential wildfire or storm damage risks; and

•Practicing sound forestry management in our service territories to create landscapes more resilient to disruption from climate-related changes, including planting and managing long-lived conifer species.

EPA Regulation of GHG Emissions. In 2019, the EPA finalized several separate rulemakings regarding regulating carbon emissions from electric utility generating units. These rulemakings included repealing the Clean Power Plan (CPP) and adopting the Affordable Clean Energy Rule under Section 111(d) of the Clean Air Act (CAA) to regulate CO2 emissions at existing coal-fired power plants. The CPP was first announced as a proposed rule under Section 111(d) of the CAA for existing power plants entitled “Carbon Pollution Emission Guidelines for Existing Stationary Sources: Electric Generating Units”. The Affordable Clean Energy Rule established emissions guidelines for states to use when developing plans to limit CO2 coal-fired power plants. The EPA also published regulations for the state implementation of the Affordable Clean Energy Rule and other Section 111(d) rules. Affected facilities for Minnesota Power included Boswell Units 3 and 4, and Taconite Harbor Units 1 and 2, which are currently economically idled.

On January 19, 2021, the D.C. Circuit issued an opinion vacating the Affordable Clean Energy Rule and remanded the Affordable Clean Energy Rule back to the EPA for further consideration, consistent with the D.C. Circuit’s finding that the EPA erred in interpreting the CAA, pending rehearing or appeal. Four petitions were subsequently granted for review by the U.S. Supreme Court on October 29, 2021, with a decision expected in mid-2022.

The EPA also indicated that it intends to issue a proposed rule in mid-2022 and a final rule in mid-2023 with a new set of emission guidelines for states to follow in submitting state plans to establish and implement standards of performance for GHG emissions from existing fossil fuel-fired electric generating units. Minnesota Power will continue to monitor any related guidelines and rulemakings issued by the EPA or state regulatory authorities.

On April 22, 2021, the Biden Administration announced a goal to reach 100 percent carbon pollution-free electricity by 2035 as part of the Nationally Determined Contributions pledge, which is part of an international effort to limit global warming. At this time, no specific regulatory pathway to achieve these reductions has been proposed. Minnesota Power will continue to monitor these developments.

Minnesota had already initiated several measures consistent with those called for under the now repealed CPP and vacated Affordable Clean Energy Rule. Minnesota Power continues implementing its EnergyForward strategic plan that provides for significant emission reductions and diversifying its electricity generation mix to include more renewable and natural gas energy. We are unable to predict the GHG emission compliance costs we might incur as a result of a replacement for the Affordable Clean Energy Rule or other future laws, regulations or administrative policies; however, the costs could be material. Minnesota Power would seek recovery of additional costs through a rate proceeding.

NOTE 8. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)

Environmental Matters (Continued)

Additionally on January 13, 2021, the EPA issued a rulemaking to apply CO2 emission New Source Performance Standards (NSPS) to new, modified and reconstructed fossil fuel-fired electric generating units under Section 111(b) of the CAA. In April 2021, the EPA requested and was allowed to voluntarily vacate and remand the Significant Contribution Finding determination criteria related to this NSPS. The EPA intends to issue a proposed rule in mid-2022 and a final rule by mid-2023. Minnesota Power is monitoring the NSPS final rule and any further Section 111(b) developments including their potential impact to the Company. The Company’s proposed combined-cycle natural gas-fired generating facility, NTEC, is expected to meet these NSPS requirements.

Water. The Clean Water Act requires NPDES permits be obtained from the EPA (or, when delegated, from individual state pollution control agencies) for any wastewater discharged into navigable waters. We have obtained all necessary NPDES permits, including NPDES storm water permits for applicable facilities, to conduct our operations.

Steam Electric Power Generating Effluent Limitations Guidelines. In 2015, the EPA issued revised federal effluent limitation guidelines (ELG) for steam electric power generating stations under the Clean Water Act. It set effluent limits and prescribed BACT for several wastewater streams, including flue gas desulphurization (FGD) water, bottom ash transport water and coal combustion landfill leachate. In 2017, the EPA announced a two-year postponement of the ELG compliance date of November 1, 2018, to November 1, 2020, while the agency reconsidered the bottom ash transport water and FGD wastewater provisions. On April 12, 2019, the U.S. Court of Appeals for the Fifth Circuit vacated and remanded back to the EPA portions of the ELG that allowed for continued discharge of legacy wastewater and leachate. On October 13, 2020, the EPA published a final ELG Rule allowing re-use of bottom ash transport water in FGD scrubber systems with limited discharges related to maintaining system water balance. The rule sets technology standards and numerical pollutant limits for discharges of bottom ash transport water and FGD wastewater. Compliance deadlines depend on subcategory, with compliance generally required as soon as possible, beginning after October 13, 2021, but no later than December 31, 2025, or December 31, 2028, in some specific cases. The rule also established new subcategories for retiring high-flow and low-utilization units, and established a voluntary incentives program for FGD wastewater. In accordance with the January 2021 Executive Order 13990, the EPA was mandated to conduct a review of actions and polices taken during the prior administration, including the 2020 ELG Rule. On September 14, 2021, the EPA published a notice of availability for preliminary effluent guidelines program plan. In the plan, the EPA confirmed the agency is initiating a rulemaking process to strengthen wastewater pollution limitations from FGD and bottom ash transport water discharges while the 2020 ELG Rule remains in effect. The EPA is expected to publish a proposed rule in the fall of 2022.

The ELG's potential impact on Minnesota Power operations is primarily at Boswell. Boswell currently discharges bottom ash contact water through its NPDES permit, and also has a closed-loop FGD system that does not discharge to surface waters, but may do so in the future. With Boswell’s planned conversion to dry FGD handling and storage, ongoing FGD water generation will be reduced, and the majority of FGD waters will be legacy waters to be dewatered from existing impoundments. Re-use and onsite consumption for the majority of FGD waters is planned at Boswell.

Under the new ELG rule, most bottom ash transport water discharge to surface waters must cease no later than December 31, 2025, except for small discharges needed to retain water balance. The majority of bottom ash transport water will either need to be re-used in a closed-loop process or routed to a FGD scrubber. At Boswell, the bottom ash handling systems are planned to be converted to a dry process, which will eliminate the discharge of bottom ash transport water.

The EPA’s additional reconsideration of legacy wastewater discharge requirements has the potential to reduce timelines for dewatering Boswell’s existing ponds. The EPA has withdrawn its separate action regarding the 2015 leachate and legacy wastewater ELGs and intends to consolidate that reconsideration with the 2020 bottom ash transport water and FGD ELG reconsideration. A proposed rule is expected in late 2022.

NOTE 8. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)

Environmental Matters (Continued)

At this time, we estimate that the planned dry conversion of bottom ash handling and storage at Boswell in response to the CCR revisions requiring closure of clay-lined impoundments, as well as other water re-use practices, will reduce or eliminate the need for additional significant compliance costs for ELG bottom ash water and FGD requirements. Compliance costs we might incur related to other ELG waste streams (e.g., legacy leachate) or other potential future water discharge regulations cannot be estimated; however, the costs could be material, including costs associated with wastewater treatment and re-use. Minnesota Power would seek recovery of additional costs through a rate proceeding.

Permitted Water Discharges – Sulfate. In 2017, the MPCA released a draft water quality standard in an attempt to update Minnesota’s existing 10 mg/L sulfate limit for waters used for the production of wild rice with the proposed rulemaking heard before an administrative law judge (ALJ). In 2018, the ALJ rejected significant portions of the proposed rulemaking and the MPCA subsequently withdrew the rulemaking. The existing 10 mg/L limit remains in place, but the MPCA is currently prohibited under state law from listing wild rice waters as impaired or requiring sulfate reduction technology.

In April 2021, the MPCA’s proposed list of impaired waters submitted pursuant to the Clean Water Act was partially rejected by the EPA due to the absence of wild rice waters listed for sulfate impairment. The EPA subsequently proposed a list of 30 wild rice waters in a separate listing process on April 29, 2021, followed by a list of three additional wild rice waters proposed separately on September 1, 2021. A final impaired waters listing is expected to follow, which could subsequently be used to set sulfate limits in discharge permits for power generation facilities and municipal and industrial customers, including paper and pulp facilities, and mining operations. At this time we are unable to determine the specific impacts these developments may have on Minnesota Power operations, if any. Minnesota Power would seek recovery of additional costs through a rate proceeding.

Solid and Hazardous Waste. The Resource Conservation and Recovery Act of 1976 regulates the management and disposal of solid and hazardous wastes. We are required to notify the EPA of hazardous waste activity and, consequently, routinely submit reports to the EPA.

Coal Ash Management Facilities. Minnesota Power produces the majority of its coal ash at Boswell, with small amounts of ash generated at Hibbard Renewable Energy Center. Ash storage and disposal methods include storing ash in clay-lined onsite impoundments (ash ponds), disposing of dry ash in a lined dry ash landfill, applying ash to land as an approved beneficial use, and trucking ash to state permitted landfills.

Coal Combustion Residuals from Electric Utilities (CCR). In 2015, the EPA published the final rule regulating CCR as nonhazardous waste under Subtitle D of the Resource Conservation and Recovery Act (RCRA) in the Federal Register. The rule includes additional requirements for new landfill and impoundment construction as well as closure activities related to certain existing impoundments. Costs of compliance for Boswell and Laskin are expected to be incurred primarily over the next 15 years and be between approximately $65 million and $120 million. Compliance costs for CCR at Taconite Harbor are not expected to be material. Minnesota Power would seek recovery of additional costs through a rate proceeding.

Minnesota Power continues to work on minimizing costs through evaluation of beneficial re-use and recycling of CCR and CCR-related waters. In 2017, the EPA announced its intention to formally reconsider the CCR rule under Subtitle D of the RCRA. In March 2018, the EPA published the first phase of the proposed rule revisions in the Federal Register. In 2018, the EPA finalized revisions to elements of the CCR rule, including extending certain deadlines by two years, the establishment of alternative groundwater protection standards for certain constituents and the potential for risk-based management options at facilities based on site characteristics. In 2018, a U.S. District Court for the District of Columbia decision vacated specific provisions of the CCR rule. The court decision resulted in a change to the status of three existing clay-lined impoundments at Boswell that must now be considered unlined. The EPA proposed additional rule revisions in 2019 to address outstanding issues from litigation and closure timelines for unlined impoundments, respectively. The first of these rules, CCR Part A Rule, was finalized in September 2020. The Part A Rule revision requires unlined impoundments to cease disposal of waste as soon as technically feasible but no later than April 11, 2021. This deadline has continued to toll as the EPA did not make any variance application determinations by that date. Minnesota Power sought EPA approval to extend the closure date for the two active Boswell impoundments in November 2020 through a variance application, and continues to operate the impoundments pending a final determination by the EPA. On January 11, 2022, the EPA issued a number of Part A and Part B variance application completeness determinations. The Boswell application was deemed complete; an approval or denial of the application is expected in mid-2022.

NOTE 8. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)

Environmental Matters (Continued)

Additionally, the EPA released a proposed Part B rulemaking in 2020 that addressed options for beneficial reuse of CCR materials, alternative liner demonstrations, and other CCR regulatory revisions. Portions of the Part B Rule addressing alternative liner equivalency standards were finalized in November 2020. According to the EPA’s regulatory agenda, finalization of the remainder of the proposed Part B Rule is expected in late 2022. Expected compliance costs at Boswell due to the court decision and subsequent rule revisions are reflected in our estimate of compliance costs for the CCR rule noted previously. Minnesota Power would seek recovery of additional costs through a rate proceeding.

Other Environmental Matters

Manufactured Gas Plant Site. We are reviewing and addressing environmental conditions at a former manufactured gas plant site located in Superior, Wisconsin, and formerly operated by SWL&P. SWL&P has been working with the Wisconsin Department of Natural Resources (WDNR) in determining the extent and location of contamination at the site and surrounding properties. As of December 31, 2021, we have recorded a liability of approximately $18 million for remediation costs at this site after further refining the scope of work and cost estimates as well as incorporating detailed design components specific to the site in 2021 (approximately $7 million as of December 31, 2020); however, SWL&P continues to work with the WDNR on the extent of contamination which may result in additional remediation costs being identified. SWL&P has also recorded an associated regulatory asset as we expect recovery of these remediation costs to be allowed by the PSCW. Remediation costs are expected to be incurred through 2023.

Commitments Contingencies and Guarantees

Other Matters

We have multiple credit facility agreements in place that provide the ability to issue standby letters of credit to satisfy our contractual security requirements across our businesses. As of December 31, 2021, we had $134.7 million of outstanding letters of credit issued, including those issued under our revolving credit facility.

Regulated Operations. As of December 31, 2021, we had $10.9 million outstanding in standby letters of credit at our Regulated Operations which are pledged as security for MISO and state agency agreements as well as energy facilities under development.

ALLETE Clean Energy. ALLETE Clean Energy’s wind energy facilities have PSAs in place for their output and expire in various years between 2022 and 2039. As of December 31, 2021, ALLETE Clean Energy has $87.4 million outstanding in standby letters of credit, the majority of which are pledged as security under these PSAs and PSAs for wind energy facilities under development.

Corporate and Other.

BNI Energy. As of December 31, 2021, BNI Energy had surety bonds outstanding of $71.2 million related to the reclamation liability for closing costs associated with its mine and mine facilities. Although its coal supply agreements obligate the customers to provide for the closing costs, additional assurance is required by federal and state regulations. BNI Energy’s total reclamation liability is currently estimated at $70.7 million. BNI Energy does not believe it is likely that any of these outstanding surety bonds will be drawn upon.

Investment in Nobles 2. Nobles 2 wind energy facility requires standby letters of credit as security for certain contractual obligations. As of December 31, 2021, ALLETE South Wind has $12.5 million outstanding in standby letters of credit, related to our portion of the security requirements relative to our ownership in Nobles 2.

South Shore Energy. As of December 31, 2021, South Shore Energy had $23.9 million outstanding in standby letters of credit pledged as security in connection with the development of NTEC. South Shore Energy does not believe it is likely that any of these outstanding letters of credit will be drawn upon.

ALLETE Properties. As of December 31, 2021, ALLETE Properties had surety bonds outstanding and letters of credit to governmental entities totaling $2.0 million primarily related to development and maintenance obligations for various projects. The estimated cost of the remaining development work is $1.0 million. ALLETE Properties does not believe it is likely that any of these outstanding surety bonds or letters of credit will be drawn upon.

NOTE 8. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)

Other Matters (Continued

Community Development District Obligations. In 2005, the Town Center District issued $26.4 million of tax-exempt, 6.0 percent capital improvement revenue bonds. The capital improvement revenue bonds are payable over 31 years (by May 1, 2036) and are secured by special assessments on the benefited land. To the extent that ALLETE Properties still owns land at the time of the assessment, it will incur the cost of its portion of these assessments, based upon its ownership of benefited property.

As of December 31, 2021, we owned 30 percent of the assessable land in the Town Center District (48 percent as of December 31, 2020). As of December 31, 2021, ownership levels, our annual assessments related to capital improvement and special assessment bonds for the ALLETE Properties project within the district is approximately $1.8 million. As we sell property at this project, the obligation to pay special assessments will pass to the new landowners. In accordance with accounting guidance, these bonds are not reflected as debt on our Consolidated Balance Sheet.

Legal Proceedings.

We are involved in litigation arising in the normal course of business. Also in the normal course of business, we are involved in tax, regulatory and other governmental audits, inspections, investigations and other proceedings that involve state and federal taxes, safety, and compliance with regulations, rate base and cost of service issues, among other things. We do not expect the outcome of these matters to have a material effect on our financial position, results of operations or cash flows.

Minnesota Power has been named in a lawsuit where a contractor performing work at one of its facilities experienced an injury and subsequently filed a lawsuit seeking compensatory damages. Litigation related to this injury is ongoing. At this time, a loss is considered reasonably possible; however, we do not deem it probable, and we are unable to estimate a loss or range of loss related to the litigation at this time.

Operations and Significant Accounting Policies - Business Segments (Details) $ in Millions		3 Months Ended	12 Months Ended
	Oct. 01, 2021 USD ($)	Dec. 31, 2021 USD ($) a Customers MW	Dec. 31, 2021 USD ($) a Customers MW	Dec. 31, 2020
Business Segments [Line Items]
Number of Reportable Segments			3	3
Square Butte [Member] \| Square Butte PPA [Member]
Business Segments [Line Items]
Minnesota Power Output Entitlement (MW) \| MW			227.5
Nemadji Trail Energy Center [Member]
Business Segments [Line Items]
Estimated Capital Expenditures, Including Past Expenditures \| $		$ 150.0	$ 150.0
Capital Cost Spent to Date \| $		$ 5.0	$ 5.0
Square Butte [Member] \| Square Butte [Member] \| Square Butte PPA [Member]
Business Segments [Line Items]
Expected Output Entitlement (Percent)			50.00%
Minnesota Power Output Entitlement (Percent)			50.00%
Generating Capacity Counterparty Owned (MW) \| MW		455	455
Regulated Operations [Member] \| Retail Customers [Member] \| Electric Rates [Member]
Business Segments [Line Items]
Number of Customers \| Customers		15,000	15,000
Regulated Operations [Member] \| Retail Customers [Member] \| Natural Gas [Member]
Business Segments [Line Items]
Number of Customers \| Customers		13,000	13,000
Regulated Operations [Member] \| Retail Customers [Member] \| Water [Member]
Business Segments [Line Items]
Number of Customers \| Customers		10,000	10,000
Regulated Operations [Member] \| Municipal Customers [Member] \| Electric Rates [Member]
Business Segments [Line Items]
Number of Customers \| Customers		15	15
ALLETE Clean Energy [Member]
Business Segments [Line Items]
Energy Generation Owned (MW) \| MW		1,300	1,300
Generating Capacity Under Construction (MW) \| MW		200	200
U.S. Water Services [Member]
Business Segments [Line Items]
Approximate Proceeds Expected or Received from Divestiture of Business \| $			$ 270.0
Corporate and Other [Member]
Business Segments [Line Items]
Land in Minnesota (Acres) \| a		4,000	4,000
Number of Customers \| Customers		2	2
Corporate and Other [Member] \| Square Butte [Member]
Business Segments [Line Items]
Number of Customers \| Customers		1	1
Corporate and Other [Member] \| Nemadji Trail Energy Center [Member]
Business Segments [Line Items]
Gain on Sale After Tax \| $	$ 8.5		$ 8.5
Approximate Sales Price \| $	$ 20.0
Nobles 2 [Member]
Business Segments [Line Items]
Ownership Percentage		49.00%	49.00%
Natural Gas-Fired [Member] \| Nemadji Trail Energy Center [Member]
Business Segments [Line Items]
Generating Capacity Jointly Owned (MW) \| MW		600	600
Expected Output Entitlement (Percent)	20.00%	20.00%
Minnesota Power Output Entitlement (Percent)	20.00%	20.00%
Natural Gas-Fired [Member] \| Basin Electric Power Cooperative [Member] \| Nemadji Trail Energy Center [Member]
Business Segments [Line Items]
Expected Output Entitlement (Percent)	30.00%
Minnesota Power Output Entitlement (Percent)	30.00%
Natural Gas-Fired [Member] \| Dairyland Power Cooperative [Member] \| Nemadji Trail Energy Center [Member]
Business Segments [Line Items]
Expected Output Entitlement (Percent)	50.00%
Minnesota Power Output Entitlement (Percent)	50.00%
Wind Turbine Generators [Member] \| Tenaska [Member] \| Nobles 2 PPA [Member]
Business Segments [Line Items]
Generating Capacity Counterparty Owned (MW) \| MW		250	250
Contract Term (Years)			20 years

Business Segment (Details)
$ in Millions

3 Months Ended

12 Months Ended

Oct. 01, 2021

USD ($)

Dec. 31, 2021

USD ($)

Sep. 30, 2021

USD ($)

Jun. 30, 2021

USD ($)

Mar. 31, 2021

USD ($)

Dec. 31, 2020

USD ($)

Sep. 30, 2020

USD ($)

Jun. 30, 2020

USD ($)

Mar. 31, 2020

USD ($)

Dec. 31, 2019

USD ($)

Sep. 30, 2019

USD ($)

Jun. 30, 2019

USD ($)

Mar. 31, 2019

USD ($)

Dec. 31, 2021

USD ($)

Dec. 31, 2020

USD ($)

Dec. 31, 2019

USD ($)

Number of Reportable Segments

$ 399.0

$ 345.4

$ 335.6

$ 339.2

$ 320.4

$ 293.9

$ 243.2

$ 311.6

$ 304.6

$ 288.3

$ 290.4

$ 357.2

$ 1,419.2

$ 1,169.1

$ 1,240.5

Other – Non-utility

11.4

11.3

11.6

61.9

$ 27.6

$ 27.9

$ 51.8

47.1

$ 40.7

$ 20.1

$ 66.3

$ 49.7

$ 31.2

$ 34.2

$ 70.5

169.2

174.2

185.6

231.7

217.8

202.0

69.1

65.6

64.9

20.0

22.1

21.7

(26.9)

(39.5)

(6.6)

6,435.0

6,084.6

6,435.0

6,084.6

Consolidation, Eliminations [Member]

476.4

657.2

Regulated Operations [Member]

^[1]

$ (2.9)

(8.3)

(5.0)

Number of Operating Segments

$ 170.7

166.9

159.4

^[1]

57.3

58.5

58.9

21.3

22.3

21.7

(16.6)

(19.4)

(7.1)

Regulated Operations [Member]

166.8

133.7

1,227.9

987.3

1,042.4

^[2]

129.1

136.3

154.4

Corporate and Other [Member]

$ 4,289.4

4,196.8

$ 4,289.4

4,196.8

Number of Operating Segments

Land in Minnesota (Acres) | a

4,000

$ 104.4

102.2

105.1

^[2],[3],[4]

13.8

8.0

19.9

11.8

13.0

13.5

^[1]

13.2

8.0

(1.3)

(0.2)

0.0

^[5]

6.3

(1.0)

12.8

$ 426.2

404.5

426.2

404.5

Gain on Sale of Affiliate, After-tax

39.7

15.7

13.2

Income Tax Expense (Benefit), Due to Sale of Subsidiary

10.4

Corporate and Other [Member] | Nemadji Trail Energy Center [Member]

ALLETE Clean Energy [Member]

Gain on Sale After Tax

$ 8.5

8.5

86.9

79.6

59.6

^[2]

26.3

29.9

12.4

49.2

37.9

26.8

^[1]

1.5

2.2

2.8

(16.6)

(19.1)

(11.9)

$ 1,719.4

$ 1,483.3

1,719.4

1,483.3

U.S. Water Services [Member]

269.9

507.8

^[3]

0.0

33.4

^[2]

0.0

(1.1)

0.0

2.3

^[1]

0.0

0.2

Residential [Member] | Regulated Operations [Member]

0.0

(0.4)

Revenue from Contract with Customer, Excluding Assessed Tax

160.8

140.7

139.6

Commercial [Member] | Regulated Operations [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

168.6

139.5

145.7

Municipal [Member] | Regulated Operations [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

52.0

41.2

48.6

Industrial [Member] | Regulated Operations [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

565.5

432.8

476.4

Other Power Suppliers [Member] | Regulated Operations [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

168.7

138.8

153.7

CIP Financial Incentive [Member] | Regulated Operations [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

^[6]

2.4

2.8

Other [Member] | Regulated Operations [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

109.9

91.9

75.6

Long-term PSA [Member] | ALLETE Clean Energy [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

75.5

68.3

48.0

ALLETE Clean Energy Other [Member] | ALLETE Clean Energy [Member]

Point-in-Time [Member] | U.S. Water Services [Member]

Other – Non-utility

11.4

11.3

11.6

Revenue from Contract with Customer, Excluding Assessed Tax

^[3]

0.0

19.0

Contract [Member] | U.S. Water Services [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

^[3]

0.0

9.2

Capital Project [Member] | U.S. Water Services [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

^[3]

0.0

5.2

Long-term Contract [Member] | Corporate and Other [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

84.4

86.0

82.8

Corporate & Other - Other [Member] | Corporate and Other [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

$ 20.0

$ 16.2

$ 22.3

[1]	Includes interest expense resulting from intercompany loan agreements and allocated to certain subsidiaries. The amounts are eliminated in consolidation.
[2]	Includes interest expense resulting from intercompany loan agreements and allocated to certain subsidiaries. The amounts are eliminated in consolidation.
[3]	In 2019, ALLETE sold U.S. Water Services. The Company recognized a gain on the sale of $13.2 million after-tax which is reflected in Corporate and Other. (See Note 1. Operations and Significant Accounting Policies.)
[4]	In 2021, South Shore Energy sold a portion of its undivided ownership interest in NTEC to Basin. The closing of the transaction resulted in the recognition of an approximately $8.5 million after-tax gain which is reflected in Corporate and Other. (See Note 1. Operations and Significant Accounting Policies.)
[5]	In 2019, ALLETE sold U.S. Water Services. The Company recognized income tax expense of $10.4 million for the gain on sale of U.S. Water Services which is reflected in Corporate and Other. (See Note 1. Operations and Significant Accounting Policies.)
[6]	See Note 4. Regulatory Matters.

Employee Stock and Incentive Plans

12 Months Ended

Dec. 31, 2021

Share-based Payment Arrangement [Abstract]

Employee Stock and Incentive Plans [Text Block]

EMPLOYEE STOCK AND INCENTIVE PLANS

Employee Stock Ownership Plan. We sponsor an ESOP within the RSOP. Eligible employees may contribute to the RSOP plan as of their date of hire. The dividends received by the ESOP are distributed to participants. Dividends on allocated ESOP shares are recorded as a reduction of retained earnings. ESOP employer allocations are funded with contributions paid in either cash or the issuance of ALLETE common stock at the Company’s discretion. We record compensation expense equal to the cash or current market price of stock contributed. ESOP compensation expense was $11.5 million in 2021 ($11.2 million in 2020; $10.8 million in 2019).

According to the accounting standards for stock compensation, unallocated shares of ALLETE common stock held and purchased by the ESOP were treated as unearned ESOP shares and not considered outstanding for earnings per share computations. All ESOP shares have been allocated to participants as of December 31, 2021, 2020 and 2019.

Stock-Based Compensation.

Stock Incentive Plan. Under our Executive Long-Term Incentive Compensation Plan (Executive Plan), share-based awards may be issued to key employees through a broad range of methods, including non-qualified and incentive stock options, performance shares, performance units, restricted stock, restricted stock units, stock appreciation rights and other awards. There are 0.7 million shares of ALLETE common stock reserved for issuance under the Executive Plan, of which 0.7 million of these shares remain available for issuance as of December 31, 2021.

NOTE 12. EMPLOYEE STOCK AND INCENTIVE PLANS (Continued)

Stock-Based Compensation (Continued)

The following types of share-based awards were outstanding in 2021, 2020 or 2019:

Performance Shares. Under the performance share awards, the number of shares earned is contingent upon attaining specific market and performance goals over a three-year performance period. Market goals are measured by total shareholder return relative to a group of peer companies while performance goals are measured by earnings per share growth. In the case of qualified retirement, death, or disability during a performance period, a pro rata portion of the award will be earned at the conclusion of the performance period based on the market goals achieved. In the case of termination of employment for any reason other than qualified retirement, death, or disability, no award will be earned. If there is a change in control, a pro rata portion of the award will be paid based on the greater of actual performance up to the date of the change in control or target performance. The fair value of these awards incorporates the probability of meeting the total shareholder return goals. Compensation cost is recognized over the three-year performance period based on our estimate of the number of shares which will be earned by the award recipients.

Restricted Stock Units. Under the restricted stock unit awards, shares for participants eligible for retirement vest monthly over a three-year period. For participants not eligible for retirement, shares vest at the end of the three-year period. In the case of qualified retirement, death or disability, a pro rata portion of the award will be earned. In the case of termination of employment for any reason other than qualified retirement, death or disability, no award will be earned. If there is a change in control, a pro rata portion of the award will be earned. The fair value of these awards is equal to the grant date fair value. Compensation cost is recognized over the three-year vesting period based on our estimate of the number of shares which will be earned by the award recipients.

Employee Stock Purchase Plan (ESPP). Under our ESPP, eligible employees may purchase ALLETE common stock at a 5 percent discount from the market price; we are not required to apply fair value accounting to these awards as the discount is not greater than 5 percent.

RSOP. The RSOP is a contributory defined contribution plan subject to the provisions of the Employee Retirement Income Security Act of 1974, as amended, and qualifies as an employee stock ownership plan and profit sharing plan. The RSOP provides eligible employees an opportunity to save for retirement.

The following share-based compensation expense amounts were recognized in our Consolidated Statement of Income for the periods presented.


Share-Based Compensation Expense
Year Ended December 31	2021	2020	2019
Millions

Performance Shares	$2.0	$2.2	$2.3
Restricted Stock Units	1.0	0.9	0.8
Total Share-Based Compensation Expense	$3.0	$3.1	$3.1
Income Tax Benefit	$0.9	$0.9	$0.9

There were no capitalized share-based compensation costs during the years ended December 31, 2021, 2020 or 2019.

As of December 31, 2021, the total unrecognized compensation cost for the performance share awards and restricted stock units not yet recognized in our Consolidated Statement of Income was $1.8 million and $0.9 million, respectively. These amounts are expected to be recognized over a weighted-average period of 1.7 years and 1.6 years, respectively.

NOTE 12. EMPLOYEE STOCK AND INCENTIVE PLANS (Continued)

Stock-Based Compensation (Continued)

Performance Shares. The following table presents information regarding our non-vested performance shares.


	2021		2020		2019
	Number of Shares	Weighted- Average Grant Date Fair Value	Number of Shares	Weighted- Average Grant Date Fair Value	Number of Shares	Weighted- Average Grant Date Fair Value
Non-vested as of January 1	85,284	$80.73	99,585	$72.78	129,693	$66.12
Granted (a)	33,304	$73.25	25,763	$83.17	60,747	$63.89
Awarded	—	—	(25,304)	$62.03	(75,943)	$53.44
Unearned Grant Award	(33,375)	$86.09	(13,625)	$62.03	—	—
Forfeited	(4,552)	$74.05	(1,135)	$79.81	(14,912)	$77.14
Non-vested as of December 31	80,661	$75.80	85,284	$80.73	99,585	$72.78

(a) Shares granted include accrued dividends.

There were approximately 32,000 performance shares granted in February 2022 for the three-year performance period ending in 2024. The ultimate issuance is contingent upon the attainment of certain goals of ALLETE during the performance periods. The grant date fair value of the performance shares granted was $2.2 million. There were no performance shares awarded in February 2022.

Restricted Stock Units. The following table presents information regarding our available restricted stock units.


	2021		2020		2019
	Number of Shares	Weighted- Average Grant Date Fair Value	Number of Shares	Weighted- Average Grant Date Fair Value	Number of Shares	Weighted- Average Grant Date Fair Value
Available as of January 1	37,482	$77.64	39,943	$69.30	49,771	$60.74
Granted (a)	16,251	$64.97	15,169	$83.48	13,927	$74.93
Awarded	(23,631)	$74.53	(17,193)	$63.41	(21,110)	$52.44
Forfeited	(1,961)	$74.52	(437)	$77.52	(2,645)	$72.43
Available as of December 31	28,141	$73.16	37,482	$77.64	39,943	$69.30

(a) Shares granted include accrued dividends.

There were approximately 13,000 restricted stock units granted in February 2022 for the vesting period ending in 2024. The grant date fair value of the restricted stock units granted was $0.8 million. There were approximately 7,000 restricted stock units awarded in February 2022. The grant date fair value of the shares awarded was $0.5 million.

Regulatory Matters

12 Months Ended

Dec. 31, 2021

Regulated Operations [Abstract]

Regulatory Matters [Text Block]

REGULATORY MATTERS

Electric Rates. Entities within our Regulated Operations segment file for periodic rate revisions with the MPUC, PSCW or FERC. As authorized by the MPUC, Minnesota Power also recognizes revenue under cost recovery riders for transmission, renewable and environmental investments and expenditures. (See Transmission Cost Recovery Rider, Renewable Cost Recovery Rider, Solar Cost Recovery Rider and Environmental Improvement Rider.) Revenue from cost recovery riders was $38.9 million in 2021 ($29.9 million in 2020; $31.8 million in 2019).

2020 Minnesota General Rate Case. In November 2019, Minnesota Power filed a retail rate increase request with the MPUC seeking an average increase of approximately 10.6 percent for retail customers. The rate filing sought a return on equity of 10.05 percent and a 53.81 percent equity ratio. On an annualized basis, the requested final rate increase would have generated approximately $66 million in additional revenue. In December 2019 orders, the MPUC accepted the filing as complete and authorized an annual interim rate increase of $36.1 million beginning January 1, 2020.

In April 2020, Minnesota Power filed a request with the MPUC that proposed a resolution of Minnesota Power’s 2020 general rate case. Key components of our proposal included removing the power marketing margin credit in base rates and reflecting actual power marketing margins in the fuel adjustment clause effective May 1, 2020; refunding to customers interim rates collected through April 2020; increasing customer rates 4.1 percent compared to the 5.8 percent increase reflected in interim rates; and a provision that Minnesota Power would not file another rate case until at least November 1, 2021, unless certain events occur. In a June 2020 order, the MPUC approved Minnesota Power’s petition and proposal to resolve and withdraw the general rate case. Effective May 1, 2020, customer rates were set at an increase of 4.1 percent with the removal of the power marketing margin credit from base rates. Actual power marketing margins will be reflected in the fuel adjustment clause. Reserves for interim rates of $11.7 million were recorded in the second quarter of 2020 and refunded in the third and fourth quarters of 2020.

2022 Minnesota General Rate Case. On November 1, 2021, Minnesota Power filed a retail rate increase request with the MPUC seeking an average increase of approximately 18 percent for retail customers. The rate filing seeks a return on equity of 10.25 percent and a 53.81 percent equity ratio. On an annualized basis, the requested final rate increase would generate approximately $108 million in additional revenue. In orders dated December 30, 2021, the MPUC accepted the filing as complete and authorized an annual interim rate increase beginning January 1, 2022, with approximately $80 million expected to be collected in cash and approximately $8 million of interim rates for residential customers deferred with a final determination on recovery at the end of the rate case.

NOTE 4. REGULATORY MATTERS (Continued)

Electric Rates (Continued)

Minnesota Power Land Sales. In August 2020, Minnesota Power filed a petition with the MPUC for approval to sell land that surrounds several reservoirs on its hydroelectric system and is no longer required to maintain its operations. The land has an estimated value of approximately $100 million, and Minnesota Power proposed to credit ratepayers the net proceeds from the sales in a future rate case or through its renewable resources rider to mitigate future rate increases. In an order dated November 18, 2021, the MPUC authorized the land sales and directed the net proceeds to be refunded to ratepayers subject to certain conditions and required compliance filings.

FERC-Approved Wholesale Rates. Minnesota Power has wholesale contracts with 15 non-affiliated municipal customers in Minnesota and SWL&P. Three of the wholesale contracts include a termination clause requiring a three-year notice to terminate.

Minnesota Power’s wholesale electric contract with the Nashwauk Public Utilities Commission was extended in October 2020 and is effective through December 31, 2037. The wholesale electric service contract with SWL&P is effective through February 28, 2025. Under the agreement with SWL&P, no termination notice has been given. The rates included in these two contracts are set each July 1 based on a cost-based formula methodology, using estimated costs and a rate of return that is equal to Minnesota Power’s authorized rate of return for Minnesota retail customers. The formula-based rate methodology also provides for a yearly true-up calculation for actual costs incurred.

Minnesota Power’s wholesale electric contracts with 13 other municipal customers were extended in January 2022 and are effective through 2029. These contracts are based on fixed prices for capacity and energy. The base energy charge for each year is adjusted annually for updated fuel and purchased power costs. The wholesale electric contract with one other municipal customer is effective through 2024. The capacity charge is determined using a cost-based formula methodology with limits on the annual change from the previous year’s capacity charge. The base energy charge for each year of the contract term is set each January 1, subject to monthly adjustment, and is determined using a cost-based formula methodology.

Transmission Cost Recovery Rider. Minnesota Power has an approved cost recovery rider in place to charge retail customers on a current basis for certain transmission investments and expenditures, including a return on the capital invested. Current customer billing rates are based on a December 2020 order. In December 2020, Minnesota Power filed a petition seeking MPUC approval to update customer billing rates for additional investments made for the GNTL. On December 28, 2021, Minnesota Power submitted its annual factor filing seeking MPUC approval to further update customer billing rates under the transmission cost recovery rider.

Renewable Cost Recovery Rider. Minnesota Power has an approved cost recovery rider in place to charge retail customers on a current basis for the costs of certain renewable investments and expenditures, including a return on the capital invested. Current customer billing rates for the renewable cost recovery rider were approved by the MPUC in a December 2020 order. On February 2, 2022, Minnesota Power submitted its 2022 renewable factor filing. Upon approval of the filing, Minnesota Power will be authorized to include updated billing rates on customer bills.

Solar Cost Recovery Rider. In June 2020, Minnesota Power filed a petition seeking MPUC approval of a customer billing rate for solar costs related to investments and expenditures for meeting the state of Minnesota’s solar energy standard, which was approved by the MPUC in an order dated April 20, 2021. New customer billing rates for the solar cost recovery rider were implemented on June 1, 2021. On October 21, 2021, Minnesota Power submitted its 2022 solar factor filing. Upon approval of the filing, Minnesota Power will be authorized to include updated billing rates on customer bills.

Environmental Improvement Rider. Minnesota Power has an approved environmental improvement rider for investments and expenditures related to the implementation of the Boswell Unit 4 mercury emissions reduction plan completed in 2015. Updated customer billing rates for the environmental improvement rider were approved by the MPUC in a November 2018 order. On January 19, 2021, Minnesota Power filed a petition seeking MPUC approval to end the environmental improvement rider, which was approved in an order dated April 20, 2021. The environmental improvement rider ended effective October 1, 2021.

Electric Vehicle Charging Infrastructure Petition. On April 8, 2021, Minnesota Power filed a petition seeking approval to install and own DC fast charger stations for electric vehicles across its service territory, implement accompanying rates for those stations, and track and recover investments and expenses for the project. In an order dated October 22, 2021, the MPUC approved Minnesota Power’s petition.

NOTE 4. REGULATORY MATTERS (Continued)

Electric Rates (Continued)

Fuel Adjustment Clause. The costs of fuel and related transportation costs for Minnesota Power’s generation as well as costs of purchased power for Minnesota Power are recoverable from Minnesota Power’s utility retail customers through the fuel adjustment clause (FAC). The FAC for Minnesota electric utilities is a monthly budgeted, forward-looking process with annual prudence review and true-up to actual allowed costs. In May 2020, Minnesota Power filed its fuel adjustment forecast for 2021, which was approved by the MPUC in a December 2020 order, subject to the annual prudence review and true-up filing in 2022. During 2021, Minnesota Power incurred higher fuel and purchased power costs than those forecasted in its May 2020 filing, which resulted in the recognition of an approximately $56 million regulatory asset as of December 31, 2021. Minnesota Power will make its annual true-up filing and a significant events filing in March 2022 requesting recovery of these under-collected fuel adjustment clause recoveries.

In March 2020, Minnesota Power filed its FAC report covering the period July 2018 through December 2019. In a September 2020 order, the MPUC referred the review of Minnesota Power’s forced outage costs during the period of the report, which totaled approximately $8 million, to an administrative law judge (ALJ) for a contested case hearing to recommend to the MPUC if any of those costs should be returned to customers. On August 11, 2021, the ALJ recommended that Minnesota Power refund approximately $5 million to ratepayers. Minnesota Power submitted exceptions to the ALJ’s report to the MPUC stating that it disagreed with the ALJ’s recommendation and that no refund should be made as the Company operated its facilities in accordance with good utility practice. At a hearing on January 13, 2022, the MPUC agreed with the ALJ’s recommendation and ordered the refund of approximately $5 million to ratepayers, which was recorded as a reserve as of December 31, 2021.

COVID-19 Related Deferred Accounting. In a March 2020 order, the PSCW authorized public utilities, including SWL&P, to defer expenditures incurred by the utility resulting from its compliance with state government or regulator orders during Wisconsin’s declared public health emergency for COVID-19. In a May 2020 order, the MPUC required Minnesota Power along with other regulated electric and natural gas service providers in Minnesota to track cost and revenue impacts resulting from the COVID-19 pandemic with review for recovery in a future rate proceeding. As of December 31, 2021, Minnesota Power has not deferred any costs or lost revenue, and SWL&P has deferred an immaterial amount of costs.

Minnesota Power submitted a petition in November 2020 to the MPUC requesting authority to track and record as a regulatory asset lost large industrial customer revenue resulting from the idling of USS Corporation’s Keetac plant and Verso Corporation’s paper mill in Duluth, Minnesota. In an order dated May 13, 2021, the MPUC denied Minnesota Power’s request.

2018 Wisconsin General Rate Case. SWL&P’s current retail rates are based on a December 2018 order by the PSCW that allows for a return on equity of 10.4 percent and a 55.0 percent equity ratio. The PSCW had directed SWL&P to file its next general rate case in 2020; however, the PSCW granted an extension request made by SWL&P to delay filing its next general rate case until on or before December 20, 2022. SWL&P requested the extension primarily due to impacts of the COVID-19 pandemic.

Integrated Resource Plan. In a 2016 order, the MPUC approved Minnesota Power’s 2015 IRP with modifications. The order accepted Minnesota Power’s plans for the economic idling of Taconite Harbor Units 1 and 2 and the ceasing of coal-fired operations at Taconite Harbor in 2020, directed Minnesota Power to retire Boswell Units 1 and 2, required an analysis of generation and demand response alternatives to be filed with a natural gas resource proposal, and required Minnesota Power to conduct requests for proposal for additional wind, solar and demand response resource additions. Minnesota Power retired Boswell Units 1 and 2 in the fourth quarter of 2018.

2021 Integrated Resource Plan. On February 1, 2021, Minnesota Power filed its latest IRP with the MPUC, which outlines its clean-energy transition plans through 2035. These plans include expanding its renewable energy supply, achieving coal-free operations at its facilities by 2035, and investing in a resilient and flexible transmission and distribution grid. As part of these plans, Minnesota Power anticipates adding approximately 400 MW of new wind and solar energy resources, retiring Boswell Unit 3 by 2030 and transforming Boswell Unit 4 to be coal-free by 2035. Minnesota Power’s plans recognize that advances in technology will play a significant role in completing its transition to carbon-free energy supply, reliably and affordably. A final decision on the IRP is expected in the second half of 2022.

NOTE 4. REGULATORY MATTERS (Continued)

Nemadji Trail Energy Center. In 2017, Minnesota Power submitted a resource package to the MPUC which included requesting approval of a natural gas capacity dedication and other affiliated-interest agreements for NTEC, an approximately 600 MW proposed combined-cycle natural gas-fired generating facility to be built in Superior, Wisconsin, which will be jointly owned by Dairyland Power Cooperative, Basin and South Shore Energy, ALLETE’s non-rate regulated, Wisconsin subsidiary. Minnesota Power is expected to purchase approximately 20 percent of the facility's output starting in 2025 pursuant to the capacity dedication agreement. (See Note 1. Operations and Significant Accounting Policies.) In a January 2019 order, the MPUC approved Minnesota Power’s request for approval of the NTEC natural gas capacity dedication and other affiliated-interest agreements. In 2019, the Minnesota Court of Appeals reversed and remanded the MPUC’s decision to approve certain affiliated-interest agreements. On April 21, 2021, the Minnesota Supreme Court reversed the Minnesota Court of Appeal’s decision by ruling that the MPUC is not required to conduct a review under the Minnesota Environmental Policy Act before approving affiliated-interest agreements that govern construction and operation of a Wisconsin power plant by a Minnesota utility, and remanded the case back to the Minnesota Court of Appeals for review of remaining issues on appeal. On August 23, 2021, the Minnesota Court of Appeals affirmed the decision by the MPUC to approve certain affiliated-interest agreements.

Conservation Improvement Program. Minnesota requires electric utilities to spend a minimum of 1.5 percent of gross operating revenues, excluding revenue received from exempt customers, from service provided in the state on energy CIPs each year.

On April 1, 2021, Minnesota Power submitted its 2020 consolidated filing detailing Minnesota Power’s CIP program results and requesting a CIP financial incentive of $2.4 million based upon MPUC procedures, which was recognized in the third quarter of 2021 upon approval by the MPUC in an order dated September 7, 2021. In 2020, a CIP financial incentive of $2.4 million was recognized in the third quarter upon approval by the MPUC of Minnesota Power’s 2019 CIP consolidated filing. CIP financial incentives are recognized in the period in which the MPUC approves the filing.

In July 2020, Minnesota Power submitted its CIP triennial filing for 2021 through 2023 to the MPUC and Minnesota Department of Commerce, which outlines Minnesota Power’s CIP spending and energy-saving goals for those years. Minnesota Power’s CIP investment goals are $10.7 million for 2022 and $10.9 million for 2023.

MISO Return on Equity Complaint. MISO transmission owners, including ALLETE and ATC, have an authorized return on equity of 10.02 percent, or 10.52 percent including an incentive adder for participation in a regional transmission organization based on a 2020 FERC order that granted rehearing of a 2019 FERC order. These FERC orders are subject to various outstanding legal challenges related to the refund period ordered by the FERC.

Minnesota Solar Energy Standard. Minnesota law requires at least 1.5 percent of total retail electric sales, excluding sales to certain customers, to be generated by solar energy. At least 10 percent of the 1.5 percent mandate must be met by solar energy generated by or procured from solar photovoltaic devices with a nameplate capacity of 40 kW or less and community solar garden subscriptions. Minnesota Power has met both parts of the solar mandate to date.

In May 2020, the MPUC issued a notice requesting all regulated gas and electric utilities provide a list of all ongoing, planned, or possible investments that support Minnesota’s energy policy objectives and aid economic recovery in Minnesota, among other items. In June 2020, Minnesota Power filed proposal with the MPUC to accelerate its plans for purchasing solar energy from approximately 20 MW of solar energy projects in Minnesota which was approved in a June 2021 order. These solar energy projects will be constructed and owned through an ALLETE subsidiary with an estimated investment of $40 million. Construction of these solar energy projects is expected to commence in 2022.

Regulatory Assets and Liabilities. Our regulated utility operations are subject to accounting standards for the effects of certain types of regulation. Regulatory assets represent incurred costs that have been deferred as they are probable for recovery in customer rates. Regulatory liabilities represent obligations to make refunds to customers and amounts collected in rates for which the related costs have not yet been incurred. The Company assesses quarterly whether regulatory assets and liabilities meet the criteria for probability of future recovery or deferral. With the exception of the regulatory asset for Boswell Units 1 and 2 net plant and equipment, no other regulatory assets are currently earning a return. The recovery, refund or credit to rates for these regulatory assets and liabilities will occur over the periods either specified by the applicable regulatory authority or over the corresponding period related to the asset or liability.

NOTE 4. REGULATORY MATTERS (Continued)


Regulatory Assets and Liabilities
As of December 31	2021	2020
Millions



Non-Current Regulatory Assets

Defined Benefit Pension and Other Postretirement Benefit Plans (a)	$226.4	$259.7

Income Taxes (b)	104.7	113.7
Cost Recovery Riders (c)	63.2	54.0
Fuel Adjustment Clause (d)	56.4	—
Asset Retirement Obligations (e)	33.1	31.6
Manufactured Gas Plant (f)	17.0	8.8
PPACA Income Tax Deferral	4.3	4.5
Conservation Improvement Program (g)	2.4	—
Boswell Units 1 and 2 Net Plant and Equipment (h)	—	5.0
Other	4.3	3.6
Total Non-Current Regulatory Assets	$511.8	$480.9


Current Regulatory Liabilities (i)

Fuel Adjustment Clause (d)	$5.0	$3.7

Transmission Formula Rates	3.1	2.9
Other	0.5	1.0
Total Current Regulatory Liabilities	8.6	7.6
Non-Current Regulatory Liabilities

Income Taxes (b)	353.4	375.3
Wholesale and Retail Contra AFUDC (j)	83.7	86.6

Plant Removal Obligations (k)	52.6	41.2
Defined Benefit Pension and Other Postretirement Benefit Plans (a)	28.1	4.4
North Dakota Investment Tax Credits (l)	12.2	12.0
Boswell Units 1 and 2 Net Plant and Equipment (h)	0.4	—
Conservation Improvement Program (g)	—	1.5


Other	5.7	3.8
Total Non-Current Regulatory Liabilities	536.1	524.8
Total Regulatory Liabilities	$544.7	$532.4

(e)Asset retirement obligations will accrete and be amortized over the lives of the related property with asset retirement obligations.

(i)Current regulatory liabilities are presented within Other Current Liabilities on the Consolidated Balance Sheet.

(k)Non-legal plant removal obligations included in retail customer rates that have not yet been incurred.

Employee Stock and Incentive Plans - Performance Shares and Restricted Stock Units (Details) - USD ($)
$ / shares in Units, $ in Millions

1 Months Ended

12 Months Ended

Feb. 28, 2022

Dec. 31, 2021

Dec. 31, 2020

Dec. 31, 2019

Performance Shares [Member]

Stock-based Compensation [Line Items]

Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Period for Recognition

1 year 8 months 12 days

85,284

99,585

129,693

^[1]

33,304

25,763

60,747

(25,304)

(75,943)

Unearned Grant Award

(33,375)

(13,625)

(4,552)

(1,135)

(14,912)

Performance Period (Years)

80,661

85,284

99,585

3 years

Weighted-Average Grant Date Fair Value [Abstract]

$ 80.73

$ 72.78

$ 66.12

^[1]

73.25

83.17

63.89

62.03

53.44

Unearned Grant Award

86.09

62.03

74.05

79.81

77.14

Restricted Stock Units [Member]

$ 75.80

$ 80.73

$ 72.78

Stock-based Compensation [Line Items]

Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Period for Recognition

1 year 7 months 6 days

37,482

39,943

49,771

^[2]

16,251

15,169

13,927

(23,631)

(17,193)

(21,110)

(1,961)

(437)

(2,645)

Performance Period (Years)

28,141

37,482

39,943

3 years

Weighted-Average Grant Date Fair Value [Abstract]

$ 77.64

$ 69.30

$ 60.74

^[2]

64.97

83.48

74.93

74.53

63.41

52.44

74.52

77.52

72.43

Subsequent Event [Member] | Performance Shares [Member]

$ 73.16

$ 77.64

$ 69.30

32,000

Performance Period (Years)

3 years

Granted, Grant Date Fair Value

$ 2.2

Subsequent Event [Member] | Restricted Stock Units [Member]

13,000

Granted, Grant Date Fair Value

(7,000)

$ 0.8

Awarded, Grant Date Fair Value

$ 0.5

[1]	Shares granted include accrued dividends.
[2]	Shares granted include accrued dividends.

Operations and Significant Accounting Policies - Balance Sheet and Income Statement Disclosures (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2021

Dec. 31, 2020

Dec. 31, 2019

Dec. 31, 2018

Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract]

Cash and Cash Equivalents

$ 45.1

$ 44.3

$ 69.3

Restricted Cash included in Prepayments and Other

0.3

0.8

2.8

Restricted Cash included in Other Non-Current Assets

2.3

20.1

20.4

Cash, Cash Equivalents and Restricted Cash on the Consolidated Statement of Cash Flows

47.7

65.2

92.5

$ 79.0

Accounts Receivable [Abstract]

Billed

100.8

93.5

Unbilled

24.7

20.9

Less: Allowance for Doubtful Accounts

1.8

2.5

Total Accounts Receivable

123.7

111.9

Inventories – Net [Abstract]

Fuel

^[1]

18.7

23.1

Materials and Supplies

56.1

51.1

Construction of Wind Energy Facilities

^[2]

22.9

0.0

Total Inventories – Net

97.7

74.2

Impairment of Long-Lived Assets Held-for-use

0.0

Other Non-Current Assets [Abstract]

Contract Asset - Noncurrent

^[3]

23.3

25.5

Operating Lease, Right-of-Use Asset

16.4

22.4

ALLETE Properties

19.4

18.2

Restricted Cash, Noncurrent

2.3

20.1

$ 20.4

Other Postretirement Benefit Plans

64.8

34.2

Total Other Non-Current Assets

87.5

86.4

213.7

206.8

Customer Deposits

^[4]

27.2

7.4

PSAs

12.6

12.5

Manufactured Gas Plant - Current

^[5]

12.8

0.0

Fuel Adjustment Clause

5.0

3.7

Operating Lease Liabilities, Current

4.8

Redeemable Non-Controlling Interest

^[6]

30.6

0.0

Total Other Current Liabilities

40.0

37.2

133.0

66.7

Asset Retirement Obligation

184.5

166.6

PSAs

39.5

52.1

Operating Lease Liabilities, Non-Current

11.6

Total Other Non-Current Liabilities

45.2

50.1

$ 280.8

$ 285.3

Income Taxes [Abstract]

More-Likely-Than-Not Percentage

50.00%

Taconite Harbor [Member] | Resource Package [Member] | MPUC [Member]

Boswell Unit 3 [Member] | 2021 Integrated Resource Plan [Member] | MPUC [Member]

Net Book Value

$ 45.0

Boswell Unit 4 [Member] | 2021 Integrated Resource Plan [Member] | MPUC [Member]

Net Book Value

245.0

Other Current Liabilities

Net Book Value

435.0

Operating Lease Liabilities, Current

4.8

$ 5.9

Other Noncurrent Liabilities

Operating Lease Liabilities, Non-Current

$ 11.6

$ 16.5

[1]	Fuel consists primarily of coal inventory at Minnesota Power.
[2]	Project costs related to ALLETE Clean Energy’s Northern Wind and Red Barn wind projects which are expected be sold in late 2022 and 2023, respectively. (See Other Current Liabilities.)
[3]	Contract Assets include payments made to customers as an incentive to execute or extend service agreements. The contract payments are being amortized over the term of the respective agreements as a reduction to revenue.
[4]	Primarily related to deposits received by ALLETE Clean Energy for the Northern Wind and Red Barn wind projects which are expected be sold in late 2022 and 2023 respectively. (See Inventories – Net.)
[5]	The manufactured gas plant represents the current liability for remediation of a former manufactured gas plant site located in Superior, Wisconsin, and formerly operated by SWL&P. (See Note 8. Commitments, Guarantees and Contingencies.)
[6]	Amount reclassified from Non-Controlling Interest in Subsidiaries resulting from the exercise of an option to buy out a non-controlling interest, which was paid in the first quarter of 2022.

Property, Plant and Equipment

12 Months Ended

Dec. 31, 2021

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment [Text Block]

PROPERTY, PLANT AND EQUIPMENT


Property, Plant and Equipment
As of December 31	2021	2020
Millions
Regulated Operations
Property, Plant and Equipment in Service	$5,028.7	$4,972.3

Construction Work in Progress	108.7	79.4
Accumulated Depreciation	(1,834.6)	(1,758.0)
Regulated Operations – Net	3,302.8	3,293.7
ALLETE Clean Energy
Property, Plant and Equipment in Service	1,716.9	1,275.4
Construction Work in Progress	79.9	261.0
Accumulated Depreciation	(149.0)	(112.9)
ALLETE Clean Energy – Net	1,647.8	1,423.5






Corporate and Other (a)
Property, Plant and Equipment in Service	267.1	240.5
Construction Work in Progress	19.8	9.6
Accumulated Depreciation	(137.3)	(126.5)
Corporate and Other – Net	149.6	123.6
Property, Plant and Equipment – Net	$5,100.2	$4,840.8

(a)Primarily includes BNI Energy and a small amount of non-rate base generation.

Depreciation is computed using the straight-line method over the estimated useful lives of the various classes of assets.

Estimated Useful Lives of Property, Plant and Equipment (Years)

Regulated Operations

Generation

2 to 50

ALLETE Clean Energy

5 to 35

Transmission

50 to 75

Corporate and Other

3 to 50

Distribution

18 to 70

NOTE 2. PROPERTY, PLANT AND EQUIPMENT (Continued)

Asset Retirement Obligations. We recognize, at fair value, obligations associated with the retirement of certain tangible, long‑lived assets that result from the acquisition, construction, development or normal operation of the asset. Asset retirement obligations (AROs) relate primarily to the decommissioning of our coal-fired and wind energy facilities, and land reclamation at BNI Energy. AROs are included in Other Non-Current Liabilities on the Consolidated Balance Sheet. The associated retirement costs are capitalized as part of the related long-lived asset and depreciated over the useful life of the asset. Removal costs associated with certain distribution and transmission assets have not been recognized, as these facilities have indeterminate useful lives.

Conditional asset retirement obligations have been identified for treated wood poles and remaining polychlorinated biphenyl and asbestos-containing assets; however, the period of remediation is indeterminable and removal liabilities have not been recognized.

Long-standing ratemaking practices approved by applicable state and federal regulatory authorities have allowed provisions for future plant removal costs in depreciation rates. These plant removal cost recoveries are classified either as AROs or as a regulatory liability for non-AROs. To the extent annual accruals for plant removal costs differ from accruals under approved depreciation rates, a regulatory asset has been established in accordance with GAAP for AROs. (See Note 4. Regulatory Matters.)


Asset Retirement Obligations
Millions
Obligation as of December 31, 2019						$160.3
Accretion						8.3
Liabilities Recognized						1.4
Liabilities Settled						(3.6)
Revisions in Estimated Cash Flows						0.2
Obligation as of December 31, 2020						166.6
Accretion						8.8
Liabilities Recognized						4.5
Liabilities Settled						(5.2)
Revisions in Estimated Cash Flows						9.8
Obligation as of December 31, 2021						$184.5

Operations and Significant Accounting Policies - Other Income (Expense) - Other (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2021

Dec. 31, 2020

Dec. 31, 2019

Pension and Other Postretirement Benefit Plans Non-Service Credit [Member]

$ 8.7

$ 14.7

$ 18.7

Interest and Investment Earnings [Member]

^[1]

6.1

8.6

7.7

2.3

1.6

4.4

AFUDC - Equity [Member]

Gain on Land Sales [Member]

2.6

1.9

2.3

Other Income (Expense) - Other [Member]

0.1

0.4

2.1

Trade Accounts Receivable [Member]

$ (2.4)

$ 2.2

[1]	These are components of net periodic pension and other postretirement benefit cost other than service cost. (See Note 11. Pension and Other Postretirement Benefit Plans.

Schedule II (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2021

Dec. 31, 2020

Dec. 31, 2019

Valuation and Qualifying Accounts and Reserves [Roll Forward]

Balance at Beginning of Period

$ 2.5

$ 0.9

$ 1.7

Additions, Charged to Income

1.2

2.7

(0.1)

Additions, Other Charges

0.0

Deductions from Reserves

^[1]

1.9

1.1

0.7

Balance at End of Period

1.8

2.5

0.9

Finance Receivables – Long-Term [Member]

Valuation and Qualifying Accounts and Reserves [Roll Forward]

Balance at Beginning of Period

0.0

Additions, Charged to Income

0.0

Additions, Other Charges

0.0

Deductions from Reserves

^[1]

0.0

Balance at End of Period

0.0

Deferred Tax Assets [Member]

Valuation and Qualifying Accounts and Reserves [Roll Forward]

Balance at Beginning of Period

69.9

70.0

66.5

Additions, Charged to Income

(0.9)

(0.1)

3.5

Additions, Other Charges

0.0

Deductions from Reserves

^[1]

0.0

Balance at End of Period

$ 69.0

$ 69.9

$ 70.0

[1]	Includes uncollectible accounts written-off.

Operations and Significant Accounting Policies

12 Months Ended

Dec. 31, 2021

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Operations and Significant Accounting Policies [Text Block]

OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES

Financial Statement Preparation. References in this report to “we,” “us,” and “our” are to ALLETE and its subsidiaries, collectively. We prepare our financial statements in conformity with GAAP. These principles require management to make informed judgments, best estimates, and assumptions that affect the reported amounts of assets, liabilities, revenue and expenses. Actual results could differ from those estimates.

Subsequent Events. The Company performed an evaluation of subsequent events for potential recognition and disclosure through the time of the financial statements issuance.

Principles of Consolidation. Our Consolidated Financial Statements include the accounts of ALLETE, all of our majority‑owned subsidiary companies and variable interest entities of which ALLETE is the primary beneficiary. All material intercompany balances and transactions have been eliminated in consolidation.

Variable Interest Entities. The accounting guidance for “Variable Interest Entities” (VIE) is a consolidation model that considers if a company has a variable interest in a VIE. A VIE is a legal entity that possesses any of the following conditions: the entity’s equity at risk is not sufficient to permit the legal entity to finance its activities without additional subordinated financial support, equity owners are unable to direct the activities that most significantly impact the legal entity’s economic performance (or they possess disproportionate voting rights in relation to the economic interest in the legal entity), or the equity owners lack the obligation to absorb the legal entity’s expected losses or the right to receive the legal entity’s expected residual returns. Entities are required to consolidate a VIE when it is determined that they have a controlling financial interest in a VIE and therefore, are the primary beneficiary of that VIE, as defined by the accounting guidance for “Variable Interest Entities.” In determining whether ALLETE is the primary beneficiary of a VIE, management considers whether ALLETE has the power to direct the most significant activities of the VIE and is obligated to absorb losses or receive the expected residual returns that are significant to the VIE. The accounting guidance for VIEs applies to certain ALLETE Clean Energy wind energy facilities and our investment in Nobles 2. (See Tax Equity Financing.)

Business Segments. We present three reportable segments: Regulated Operations, ALLETE Clean Energy and U.S. Water Services. Our segments were determined in accordance with the guidance on segment reporting. We measure performance of our operations through budgeting and monitoring of contributions to consolidated net income by each business segment.

Regulated Operations includes our regulated utilities, Minnesota Power and SWL&P, as well as our investment in ATC, a Wisconsin-based regulated utility that owns and maintains electric transmission assets in portions of Wisconsin, Michigan, Minnesota and Illinois. Minnesota Power provides regulated utility electric service in northeastern Minnesota to approximately 150,000 retail customers. Minnesota Power also has 15 non-affiliated municipal customers in Minnesota. SWL&P is a Wisconsin utility and a wholesale customer of Minnesota Power. SWL&P provides regulated utility electric, natural gas and water service in northwestern Wisconsin to approximately 15,000 electric customers, 13,000 natural gas customers and 10,000 water customers. Our regulated utility operations include retail and wholesale activities under the jurisdiction of state and federal regulatory authorities.

ALLETE Clean Energy focuses on developing, acquiring, and operating clean and renewable energy projects. ALLETE Clean Energy currently owns and operates, in seven states, more than 1,300 MW of nameplate capacity wind energy generation that is contracted under PSAs of various durations. In addition, ALLETE Clean Energy currently has approximately 200 MW of wind energy facilities under contract for sale to others. ALLETE Clean Energy also engages in the development of wind energy facilities to operate under long-term PSAs or for sale to others upon completion.

U.S. Water Services provided integrated water management for industry by combining chemical, equipment, engineering and service for customized solutions to reduce water and energy usage, and improve efficiency. In March 2019, the Company sold U.S. Water Services to a subsidiary of Kurita Water Industries Ltd. pursuant to a stock purchase agreement for approximately $270 million in cash, net of transaction costs and cash retained.

NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)

Corporate and Other is comprised of BNI Energy, our investment in Nobles 2, South Shore Energy, ALLETE Properties, other business development and corporate expenditures, unallocated interest expense, a small amount of non-rate base generation, approximately 4,000 acres of land in Minnesota, and earnings on cash and investments.

BNI Energy mines and sells lignite coal to two North Dakota mine-mouth generating units, one of which is Square Butte. In 2021, Square Butte supplied 50 percent (227.5 MW) of its output to Minnesota Power under long-term contracts. (See Note 8. Commitments, Guarantees and Contingencies.)

Our investment in Nobles 2 represents a 49 percent equity interest in Nobles 2, the entity that owns and operates a 250 MW wind energy facility in southwestern Minnesota pursuant to a 20-year PPA with Minnesota Power.

South Shore Energy, ALLETE’s non-rate regulated, Wisconsin subsidiary, is developing NTEC, an approximately 600 MW proposed combined-cycle natural gas-fired generating facility to be built in Superior, Wisconsin, which will be jointly owned by Dairyland Power Cooperative, Basin and South Shore Energy. Minnesota Power is expected to purchase approximately 20 percent of the facility's output starting in 2025 pursuant to a capacity dedication agreement. Construction of NTEC is subject to obtaining additional permits from local, state and federal authorities. The total project cost is estimated to be approximately $700 million, of which South Shore Energy’s portion is expected to be approximately $150 million. South Shore Energy’s portion of NTEC project costs incurred through December 31, 2021, is approximately $5 million.

On October 1, 2021, South Shore Energy sold a portion of its undivided ownership interest in NTEC for approximately $20 million representing reimbursement of current costs plus a fee for prior development costs and risks incurred. Following the transaction, South Shore Energy now owns a 20 percent undivided ownership interest in NTEC, Basin owns a 30 percent undivided ownership interest in NTEC and Dairyland Power Cooperative continues to own a 50 percent undivided ownership interest in NTEC. The closing of the transaction resulted in the recognition of an approximately $8.5 million after-tax gain recorded in Corporate and Other in the fourth quarter of 2021, related to prior development costs and risks incurred.

ALLETE Properties represents our legacy Florida real estate investment. Our strategy incorporates the possibility of a bulk sale of the entire ALLETE Properties portfolio. Proceeds from a bulk sale would be strategically deployed to support growth at our Regulated Operations and ALLETE Clean Energy. ALLETE Properties continues to pursue sales of individual parcels over time and will continue to maintain key entitlements and infrastructure.

Cash, Cash Equivalents and Restricted Cash. We consider all investments purchased with original maturities of three months or less to be cash equivalents. As of December 31, 2021, and 2020, restricted cash amounts included in Prepayments and Other on the Consolidated Balance Sheet include collateral deposits required under an ALLETE Clean Energy loan agreement. The December 31, 2019 amount also includes deposits required under tax equity financing agreements. The restricted cash amounts included in Other Non-Current Assets represent collateral deposits required under an ALLETE Clean Energy loan agreement and PSAs. The December 31, 2020 and 2019 amounts also include deposits required under tax equity financing agreements. The following table provides a reconciliation of cash, cash equivalents and restricted cash reported within the Consolidated Balance Sheet that aggregate to the amounts presented in the Consolidated Statement of Cash Flows.


Cash, Cash Equivalents and Restricted Cash
As of December 31	2021	2020	2019
Millions
Cash and Cash Equivalents	$45.1	$44.3	$69.3
Restricted Cash included in Prepayments and Other	0.3	0.8	2.8
Restricted Cash included in Other Non-Current Assets	2.3	20.1	20.4
Cash, Cash Equivalents and Restricted Cash on the Consolidated Statement of Cash Flows	$47.7	$65.2	$92.5

NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)

Supplemental Statement of Cash Flow Information.


Consolidated Statement of Cash Flows
Year Ended December 31	2021	2020	2019
Millions
Cash Paid During the Period for Interest – Net of Amounts Capitalized	$66.8	$62.0	$63.5
Recognition of Right-of-use Assets and Lease Liabilities (a)	—	—	28.7





Noncash Investing and Financing Activities
Increase (Decrease) in Accounts Payable for Capital Additions to Property, Plant and Equipment	$(14.0)	$(67.0)	$33.9
Reclassification of Redeemable Non-Controlling Interest to Current Liabilities (b)	$30.6	—	—
Capitalized Asset Retirement Costs	$16.9	$4.1	$20.7


AFUDC–Equity	$2.6	$1.9	$2.3

(a)Amount of the right-of-use asset and lease liability recognized with the adoption of an accounting standards update for leases.

(b)Amount reclassified to Current Liabilities resulting from the exercise of an option to buy out a non-controlling interest.

Accounts Receivable. Accounts receivable are reported on the Consolidated Balance Sheet net of an allowance for doubtful accounts. The allowance is based on our evaluation of the receivable portfolio under current conditions, overall portfolio quality, review of specific situations and such other factors that, in our judgment, deserve recognition in estimating losses.


Accounts Receivable
As of December 31	2021	2020
Millions
Trade Accounts Receivable
Billed	$100.8	$93.5
Unbilled	24.7	20.9
Less: Allowance for Doubtful Accounts	1.8	2.5


Total Accounts Receivable	$123.7	$111.9

Concentration of Credit Risk. We are subject to concentration of credit risk primarily as a result of accounts receivable. Minnesota Power sells electricity to eight Large Power Customers. Receivables from these customers totaled $7.8 million as of December 31, 2021 ($10.3 million as of December 31, 2020). Minnesota Power does not obtain collateral to support utility receivables, but monitors the credit standing of major customers. In addition, Minnesota Power, as permitted by the MPUC, requires its taconite-producing Large Power Customers to pay weekly for electric usage based on monthly energy usage estimates, which allows us to closely manage collection of amounts due. Minnesota Power’s taconite customers, which are currently owned by two entities at the end of 2021, accounted for approximately 32 percent of Regulated Operations operating revenue and approximately 28 percent of consolidated operating revenue in 2021 (29 percent of Regulated Operations operating revenue and 25 percent of consolidated operating revenue in 2020). In 2019, a single entity accounted for approximately 14 percent of Regulated Operations operating revenue and 12 percent of consolidated operating revenue.

Long-Term Finance Receivables. Long-term finance receivables relating to our real estate operations are collateralized by property sold, accrue interest at market-based rates and are net of an allowance for doubtful accounts. We assess delinquent finance receivables by comparing the balance of such receivables to the estimated fair value of the collateralized property. If the fair value of the property is less than the finance receivable, we record a reserve for the difference. We estimate fair value based on recent property tax assessed values or current appraisals.

Available-for-Sale Securities. Available-for-sale debt and equity securities are recorded at fair value. Unrealized gains and losses on available-for-sale debt securities are included in accumulated other comprehensive income (loss), net of tax. Unrealized gains and losses on available-for-sale equity securities are recognized in earnings. We use the specific identification method as the basis for determining the cost of securities sold.

Inventories – Net. Inventories are stated at the lower of cost or net realizable value. Inventories in our Regulated Operations segment are carried at an average cost or first-in, first-out basis. Inventories in our ALLETE Clean Energy segment and Corporate and Other businesses are carried at an average cost, first-in, first-out or specific identification basis.

NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)


Inventories – Net
As of December 31	2021	2020
Millions
Fuel (a)	$18.7	$23.1
Materials and Supplies	56.1	51.1
Construction of Wind Energy Facilities (b)	22.9	—




Total Inventories – Net	$97.7	$74.2

(a) Fuel consists primarily of coal inventory at Minnesota Power.

(b) Project costs related to ALLETE Clean Energy’s Northern Wind and Red Barn wind projects which are expected be sold in late 2022 and 2023, respectively. (See Other Current Liabilities.)

Property, Plant and Equipment. Property, plant and equipment are recorded at original cost and are reported on the Consolidated Balance Sheet net of accumulated depreciation. Expenditures for additions, significant replacements, improvements and major plant overhauls are capitalized; maintenance and repair costs are expensed as incurred. Gains or losses on property, plant and equipment for Corporate and Other operations are recognized when they are retired or otherwise disposed. When property, plant and equipment in our Regulated Operations and ALLETE Clean Energy segments are retired or otherwise disposed, no gain or loss is recognized in accordance with the accounting standards for component depreciation except for certain circumstances where the retirement is unforeseen or unexpected. Our Regulated Operations capitalize AFUDC, which includes both an interest and equity component. AFUDC represents the cost of both debt and equity funds used to finance utility plant additions during construction periods. AFUDC amounts capitalized are included in rate base and are recovered from customers as the related property is depreciated. Upon MPUC approval of cost recovery, the recognition of AFUDC ceases. (See Note 2. Property, Plant and Equipment.)

Impairment of Long-Lived Assets. We review our long-lived assets for indicators of impairment in accordance with the accounting standards for property, plant and equipment on a quarterly basis. This includes our property, plant and equipment (see Property, Plant and Equipment) and land inventory. Land inventory is accounted for as held for use and is recorded at cost, unless the carrying value is determined not to be recoverable in accordance with the accounting standards for property, plant and equipment, in which case the land inventory is written down to estimated fair value.

In accordance with the accounting standards for property, plant and equipment, if indicators of impairment exist, we test our long‑lived assets for recoverability by comparing the carrying amount of the asset to the undiscounted future net cash flows expected to be generated by the asset. Cash flows are assessed at the lowest level of identifiable cash flows. The undiscounted future net cash flows are impacted by trends and factors known to us at the time they are calculated and our expectations related to: management’s best estimate of future use; sales prices; holding period and timing of sales; method of disposition; and future expenditures necessary to maintain the operations.

We continue to monitor changes in the broader energy markets along with wind resource expectations that could indicate impairment at ALLETE Clean Energy wind energy facilities upon contract expirations. A continued decline in energy prices or lower wind resource expectations could result in a future impairment.

In 2021, 2020, and 2019, there were no indicators of impairment for our property, plant, and equipment or land inventory. As a result, no impairment was recorded in 2021, 2020 or 2019.

NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)

Derivatives. ALLETE is exposed to certain risks relating to its business operations that can be managed through the use of derivative instruments. ALLETE may enter into derivative instruments to manage those risks including interest rate risk related to certain variable-rate borrowings and commodity price risk related to sales to retail and municipal customers as well as other power suppliers. We have determined that either these agreements are not derivatives, or, if they are derivatives, the agreements qualify for the normal purchases and normal sales exception to derivative accounting guidance; therefore, derivative accounting is not required.

Accounting for Stock-Based Compensation. We apply the fair value recognition guidance for share-based payments. Under this guidance, we recognize stock-based compensation expense for all share-based payments granted, net of an estimated forfeiture rate. (See Note 12. Employee Stock and Incentive Plans.)


Other Non-Current Assets
As of December 31	2021	2020
Millions
Contract Assets (a)	$23.3	$25.5

Operating Lease Right-of-use Assets	16.4	22.4
ALLETE Properties	19.4	18.2
Restricted Cash	2.3	20.1
Other Postretirement Benefit Plans	64.8	34.2
Other	87.5	86.4
Total Other Non-Current Assets	$213.7	$206.8


Other Current Liabilities
As of December 31	2021	2020
Millions
Customer Deposits (a)	$27.2	$7.4
PSAs	12.6	12.5



Manufactured Gas Plant (b)	12.8	—
Fuel Adjustment Clause	5.0	3.7
Operating Lease Liabilities	4.8	5.9
Redeemable Non-Controlling Interest (c)	30.6	—
Other	40.0	37.2
Total Other Current Liabilities	$133.0	$66.7

(c) Amount reclassified from Non-Controlling Interest in Subsidiaries resulting from the exercise of an option to buy out a non-controlling interest, which was paid in the first quarter of 2022.


Other Non-Current Liabilities
As of December 31	2021	2020
Millions
Asset Retirement Obligation	$184.5	$166.6
PSAs	39.5	52.1
Operating Lease Liabilities	11.6	16.5
Other	45.2	50.1
Total Other Non-Current Liabilities	$280.8	$285.3

NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)

Leases.

We determine if a contract is, or contains, a lease at inception and recognize a right-of-use asset and lease liability for all leases with a term greater than 12 months. Our right-of-use assets and lease liabilities for operating leases are included in Other Non-Current Assets, Other Current Liabilities and Other Non-Current Liabilities, respectively, in our Consolidated Balance Sheet. We currently do not have any finance leases.

Right-of-use assets represent our right to use an underlying asset for the lease term and lease liabilities represent the obligation to make lease payments arising from the lease. Operating lease right-of-use assets and lease liabilities are recognized at the commencement date based on the estimated present value of lease payments over the lease term. As our leases do not provide an explicit rate, we determine the present value of future lease payments based on our estimated incremental borrowing rate using information available at the lease commencement date. The operating lease right-of-use asset includes lease payments to be made during the lease term and any lease incentives, as applicable.

Our leases may include options to extend or buy out the lease at certain points throughout the term, and if it is reasonably certain at lease commencement that we will exercise that option, we include those rental payments in our calculation of the right-of-use asset and lease liability. Lease and rent expense is recognized on a straight-line basis over the lease term. Leases with a term of 12 months or less are not recognized on the Consolidated Balance Sheet.

The majority of our operating leases are for heavy equipment, vehicles and land with fixed monthly payments which we group into two categories: Vehicles and Equipment; and Land and Other. Our largest operating lease is for the dragline at BNI Energy which includes a termination payment at the end of the lease term if we do not exercise our purchase option. The amount of this payment is $3 million and is included in our calculation of the right-of-use asset and lease liability recorded. None of our other leases contain residual value guarantees.

Additional information on the components of lease cost and presentation of cash flows were as follows:


As December 31	2021	2020
Millions
Operating Lease Cost	$6.7	$8.3

Other Information:
Operating Cash Flows From Operating Leases	$6.7	$8.3

Additional information related to leases was as follows:


As of December 31	2021		2020
Millions

Balance Sheet Information Related to Leases:
Other Non-Current Assets	$16.4		$22.4
Total Operating Lease Right-of-use Assets	$16.4		$22.4

Other Current Liabilities	$4.8		$5.9
Other Non-Current Liabilities	11.6		16.5
Total Operating Lease Liabilities	$16.4		$22.4

Weighted Average Remaining Lease Term (Years):
Operating Leases - Vehicles and Equipment	3		3
Operating Leases - Land and Other	27		27

Weighted Average Discount Rate:
Operating Leases - Vehicles and Equipment	3.8	%	3.1	%
Operating Leases - Land and Other	4.5	%	4.1	%

NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)

Leases (Continued)

Maturities of lease liabilities were as follows:


												December 31, 2021
Millions
2022												$5.1
2023												3.3
2024												3.0
2025												2.8
2026												2.8
Thereafter												5.0
Total Lease Payments Due												22.0
Less: Imputed Interest												5.6
Total Lease Obligations												16.4
Less: Current Lease Obligations												4.8
Total Long-term Lease Obligations												$11.6

Environmental Liabilities. We review environmental matters on a quarterly basis. Accruals for environmental matters are recorded when it is probable that a liability has been incurred and the amount of the liability can be reasonably estimated based on current law and existing technologies. Accruals are adjusted as assessment and remediation efforts progress, or as additional technical or legal information becomes available. Accruals for environmental liabilities are included in the Consolidated Balance Sheet at undiscounted amounts and exclude claims for recoveries from insurance or other third parties. Costs related to environmental contamination treatment and cleanup are expensed unless recoverable in rates from customers. (See Note 8. Commitments, Guarantees and Contingencies.)

Revenue.

Contracts with Customers – Utility includes sales from our regulated operations for generation, transmission and distribution of electric service, and distribution of water and gas services to our customers. Also included is an immaterial amount of regulated steam generation that is used by customers in the production of paper and pulp.

Contracts with Customers – Non-utility includes sales of goods and services to customers from ALLETE Clean Energy, U.S. Water Services and our Corporate and Other businesses.

Other – Non-utility is the non-cash adjustments to revenue recognized by ALLETE Clean Energy for the amortization of differences between contract prices and estimated market prices for PSAs that were assumed during the acquisition of various wind energy facilities.

Revenue Recognition. Revenue is recognized upon transfer of control of promised goods or services to our customers in an amount that reflects the consideration we expect to receive in exchange for those products or services. Revenue is recognized net of allowance for returns and any taxes collected from customers, which are subsequently remitted to the appropriate governmental authorities. We account for shipping and handling activities that occur after the customer obtains control of goods as a cost rather than an additional performance obligation thereby recognizing revenue at time of shipment and accruing shipping and handling costs when control transfers to our customers. We have a right to consideration from our customers in an amount that corresponds directly with the value to the customer for our performance completed to date; therefore, we may recognize revenue in the amount to which we have a right to invoice.

NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)

Revenue (Continued)

Nature of Revenue Streams

Utility

Residential and Commercial includes sales for electric, gas or water service to customers, who have implied contracts with the utility, under rates governed by the MPUC, PSCW or FERC. Customers are billed on a monthly cycle basis and revenue is recognized for electric, gas or water service delivered during the billing period. Revenue is accrued for service provided but not yet billed at period end. Performance obligations with these customers are satisfied at time of delivery to customer meters and simultaneously consumed.

Municipal includes sales to 15 non-affiliated municipal customers in Minnesota under long-term wholesale electric contracts. All wholesale electric contracts include a termination clause requiring a three-year notice to terminate. These contracts have termination dates ranging through 2037, with a majority of contracts effective through 2029. Performance obligations with these customers are satisfied at the time energy is delivered to an agreed upon municipal substation or meter.

Industrial includes sales recognized from contracts with customers in the taconite mining, paper, pulp and secondary wood products, pipeline and other industries. Industrial sales accounted for approximately 47 percent of total regulated utility kWh sales for the year ended December 31, 2021. Within industrial revenue, Minnesota Power had eight Large Power Customer contracts, each serving requirements of 10 MW or more of customer load as of December 31, 2021. These contracts automatically renew past the contract term unless a four-year advanced written notice is given. Large Power Customer contracts have earliest termination dates ranging from 2025 through 2029. In January 2021, Verso Corporation provided notice of termination for its contract. Minnesota Power and Verso Corporation mutually agreed to resolve the outstanding commitments under the contract in January 2022. We satisfy our performance obligations for these customers at the time energy is delivered to an agreed upon customer substation. Revenue is accrued for energy provided but not yet billed at period end. Based on current contracts with industrial customers, we expect to recognize minimum revenue for the fixed contract components of approximately $50 million per annum through 2025, $15 million in 2026, and $30 million in total thereafter, which reflects the termination notice period in these contracts. When determining minimum revenue, we assume that customer contracts will continue under the contract renewal provision; however, if long-term contracts are renegotiated and subsequently approved by the MPUC or there are changes within our industrial customer class, these amounts may be impacted. Contracts with customers that contain variable pricing or quantity components are excluded from the expected minimum revenue amounts.

Other Power Suppliers includes the sale of energy under a long-term PSA with one customer as well as MISO market and liquidation sales. The expiration date of this PSA is 2028. Performance obligations with these customers are satisfied at the time energy is delivered to an agreed upon delivery point defined in the contract (generally the MISO pricing node). The current contract with one customer contains variable pricing components that prevent us from estimating future minimum revenue.

Other Revenue includes all remaining individually immaterial revenue streams for Minnesota Power and SWL&P, and is comprised of steam sales to paper and pulp mills, wheeling revenue and other sources. Revenue for steam sales to customers is recognized at the time steam is delivered and simultaneously consumed. Revenue is recognized at the time each performance obligation is satisfied.

CIP Financial Incentive reflects certain revenue that is a result of the achievement of certain objectives for our CIP financial incentives. This revenue is accounted for in accordance with the accounting standards for alternative revenue programs which allow for the recognition of revenue under an alternative revenue program if the program is established by an order from the utility’s regulatory commission, the order allows for automatic adjustment of future rates, the amount of revenue recognized is objectively determinable and probable of recovery, and the revenue will be collected within 24 months following the end of the annual period in which it is recognized. CIP financial incentives are recognized in the period in which the MPUC approves the filing, which is typically mid-year.

NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)

Revenue (Continued)

Non-utility

ALLETE Clean Energy

Long-term PSA revenue includes all sales recognized under long-term contracts for production, curtailment, capacity and associated renewable energy credits from ALLETE Clean Energy wind energy facilities. Expiration dates of these PSAs range from 2022 through 2039. Performance obligations for these contracts are satisfied at the time energy is delivered to an agreed upon point, or production is curtailed at the request of the customer, at specified prices. Revenue from the sale of renewable energy credits is recognized at the same time the related energy is delivered to the customer when sold to the same party.

Sale of Wind Energy Facility includes revenue recognized for the design, development, construction, and sale of a wind energy facility to a customer. Performance obligations for these types of agreements are satisfied at the time the completed project is transferred to the customer at the commercial operation date. Revenue from the sale of a wind energy facility is recognized at the time of asset transfer.

Other is the non-cash adjustments to revenue recognized by ALLETE Clean Energy for the amortization of differences between contract prices and estimated market prices on assumed PSAs. As part of wind energy facility acquisitions, ALLETE Clean Energy assumed various PSAs that were above or below estimated market prices at the time of acquisition; the resulting differences between contract prices and estimated market prices are amortized to revenue over the remaining PSA term.

U.S. Water Services

In 2019, ALLETE completed the sale of U.S. Water Services. Prior to the sale, ALLETE recognized revenue under the point-in-time, contract and capital project streams. Point-in-time revenue was recognized for purchases by customers for chemicals, consumable equipment or related maintenance and repair services as the customer’s usage and needs changed over time. Contract revenue included monthly revenue from contracts with customers to provide chemicals, consumable equipment and services to meet customer needs during the contract period at a fixed monthly price. Capital Project revenue was recognized at the time of sale when equipment and other components were assembled to create a water treatment system for a customer.

Corporate and Other

Long-term Contract encompasses the sale and delivery of coal to customer generation facilities. Revenue is recognized on a monthly basis at the cost of production plus a specified profit per ton of coal delivered to the customer. Coal sales are secured under long-term coal supply agreements extending through 2037. Performance obligations are satisfied during the period as coal is delivered to customer generation facilities.

Other primarily includes revenue from BNI Energy unrelated to coal, the sale of real estate from ALLETE Properties, and non‑rate base steam generation that is sold for use during production of paper and pulp. Performance obligations are satisfied when control transfers to the customer.

Payment Terms

Payment terms and conditions vary across our businesses. Aside from taconite-producing Large Power Customers, payment terms generally require payment to be made within 15 to 30 days from the end of the period that the service has been rendered. In the case of its taconite-producing Large Power Customers, as permitted by the MPUC, Minnesota Power requires weekly payments for electric usage based on monthly energy usage estimates. These customers receive estimated bills based on Minnesota Power’s estimate of the customers’ energy usage, forecasted energy prices and fuel adjustment clause estimates. Minnesota Power’s taconite-producing Large Power Customers have generally predictable energy usage on a weekly basis and any differences that occur are trued-up the following month. Due to the timing difference of revenue recognition from the timing of invoicing and payment, the taconite-producing Large Power Customers receive credit for the time value of money; however, we have determined that our contracts do not include a significant financing component as the period between when we transfer the service to the customer and when they pay for such service is minimal.

NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)

Revenue (Continued)

Assets Recognized From the Costs to Obtain a Contract with a Customer

We recognize as an asset the incremental costs of obtaining a contract with a customer if we expect the benefit of those costs to be longer than one year. We expense incremental costs when the asset that would have resulted from capitalizing these costs would have been amortized in one year or less. As of December 31, 2021, we have $23.3 million of assets recognized for costs incurred to obtain contracts with our customers ($25.5 million as of December 31, 2020). Management determined the amount of costs to be recognized as assets based on actual costs incurred and paid to obtain and fulfill these contracts to provide goods and services to our customers. Assets recognized to obtain contracts are amortized on a straight-line basis over the contract term as a non-cash reduction to revenue. We recognized $2.7 million of non-cash amortization for the year ended December 31, 2021 ($2.6 million for the year end December 31, 2020).

Unamortized Discount and Premium on Debt. Discount and premium on debt are deferred and amortized over the terms of the related debt instruments using a method which approximates the effective interest method.

Tax Equity Financings. Certain subsidiaries of ALLETE have entered into tax equity financings that include forming limited liability companies (LLC) with third-party investors for certain wind projects. Tax equity financings have specific terms that dictate distributions of cash and the allocation of tax attributes among the LLC members, who are divided into two categories: the sponsor and third-party investors. ALLETE subsidiaries are the sponsors in these tax equity financings. The distributions of cash and allocation of tax attributes in these financings generally differ from the underlying percentage ownership interests in the related LLC, with a disproportionate share of tax attributes (including accelerated depreciation and production tax credits) allocated to third-party investors in order to achieve targeted after-tax rates of return, or target yield, from project operations, and a disproportionate share of cash distributions made to the sponsor.

The target yield and other terms vary by tax equity financing. Once the target yield has been achieved, a “flip point” is recognized. In addition, tax equity financings typically provide that cash distributions can be temporarily increased to the third-party investors in order to meet cumulative distribution thresholds. After the flip point, tax attributes and cash distributions are both typically disproportionately allocated to the sponsor.

Tax equity financings include affirmative and negative covenants that are similar to what a project lender would require in a project financing, such as financial reporting, insurance, maintenance and prudent operator standards. Most covenants are no longer applicable once the flip point occurs and any other obligations of the third-party investor have been eliminated.

The third-party investors’ portions of equity ownership in tax equity LLCs are recorded as non-controlling interest in subsidiaries on the Consolidated Balance Sheet and earnings allocated to third-party investors are recorded as net loss attributable to non-controlling interest on the Consolidated Statement of Income.

Non-Controlling Interest in Subsidiaries. Non-controlling interest in subsidiaries represents the portion of equity ownership, net income (loss), and comprehensive income (loss) in subsidiaries that is not attributable to equity holders of ALLETE. These amounts as of and for the years ended December 31, 2021 and 2020, related to the tax equity financings for ALLETE Clean Energy’s 106 MW Glen Ullin, 80 MW South Peak, 303 MW Diamond Spring and 303 MW Caddo wind energy facilities as well as ALLETE’s equity investment in the 250 MW Nobles 2 wind energy facility.

For those wind projects with tax equity financings where the economic benefits are not allocated based on the underlying ownership percentage interests, we have determined that the appropriate methodology for calculating the non-controlling interest in subsidiaries balance is the hypothetical liquidation at book value (HLBV) method. The HLBV method is a balance sheet approach which reflects the substantive economic arrangements in the tax equity financing structures.

NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)

Non-Controlling Interest in Subsidiaries (Continued)

Under the HLBV method, amounts reported as non-controlling interest in subsidiaries on the Consolidated Balance Sheet represent the amounts the third-party investors would hypothetically receive at each balance sheet reporting date under the liquidation provisions of the LLC agreements, assuming the net assets of the wind projects were liquidated at amounts determined in accordance with GAAP and distributed to the third-party investor and sponsor. The resulting non-controlling interest in subsidiaries balance in these projects is reported as a component of equity on the Consolidated Balance Sheet.

The results of operations for these projects attributable to non-controlling interest under the HLBV method is determined as the difference in non-controlling interest in subsidiaries on the Consolidated Balance Sheet at the start and end of each reporting period, after taking into account any capital transactions between the projects and the third-party investors.

Factors used in the HLBV calculation include GAAP income, taxable income (loss), tax attributes such as accelerated depreciation and production tax credits, capital contributions, cash distributions, and the target yield specified in the corresponding LLC agreement. Changes in these factors could have a significant impact on the amounts that third-party investors and sponsors would receive upon a hypothetical liquidation. The use of the HLBV method to allocate income to the non-controlling interest in subsidiaries may create variability in our results of operations as the application of the HLBV method can drive variability in net income or loss attributable to non-controlling interest in subsidiaries from period to period.


Other Income (Expense) - Other
Year Ended December 31	2021	2020	2019
Millions
Pension and Other Postretirement Benefit Plan Non-Service Credit (a)	$6.1	$8.6	$7.7
Interest and Investment Earnings	2.3	1.6	4.4
AFUDC - Equity	2.6	1.9	2.3
Gain on Land Sales	0.1	0.4	2.1
Other	(2.4)	2.2	2.2
Total Other Income (Expense) - Other	$8.7	$14.7	$18.7

(a)These are components of net periodic pension and other postretirement benefit cost other than service cost. (See Note 11. Pension and Other Postretirement Benefit Plans.)

Income Taxes. ALLETE and its subsidiaries file a consolidated federal income tax return as well as combined and separate state income tax returns. We account for income taxes using the liability method in accordance with GAAP for income taxes. Under the liability method, deferred income tax assets and liabilities are established for all temporary differences in the book and tax basis of assets and liabilities, based upon enacted tax laws and rates applicable to the periods in which the taxes become payable.

Due to the effects of regulation on Minnesota Power and SWL&P, certain adjustments made to deferred income taxes are, in turn, recorded as regulatory assets or liabilities. Federal investment tax credits have been recorded as deferred credits and are being amortized to income tax expense over the service lives of the related property. In accordance with GAAP for uncertainty in income taxes, we are required to recognize in our financial statements the largest tax benefit of a tax position that is “more‑likely‑than‑not” to be sustained on audit, based solely on the technical merits of the position as of the reporting date. The term “more‑likely‑than‑not” means more than 50 percent likely. (See Note 10. Income Tax Expense.)

Excise Taxes. We collect excise taxes from our customers levied by governmental entities. These taxes are stated separately on the billing to the customer and recorded as a liability to be remitted to the governmental entity. We account for the collection and payment of these taxes on a net basis.

Regulatory Matters - Conservation Improvement Program (CIP) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Regulatory Matters [Line Items]
Conservation Improvement Program Goal, Next Fiscal Year	$ 10.7
Conservation Improvement Program Goal, In 2 Years	10.9
MPUC [Member] \| CIP Consolidated Filing [Member]
Regulatory Matters [Line Items]
CIP Financial Incentive	$ 2.4	$ 2.4
MPUC [Member] \| Minimum [Member]
Regulatory Matters [Line Items]
CIP Spending Minimum - Percentage	1.50%

Operations and Significant Accounting Policies - Lease Maturities (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Lessee, Lease, Description [Line Items]
2022	$ 5.1
2023	3.3
2024	3.0
2025	2.8
2026	2.8
Thereafter	5.0
Total Lease Payments Due	22.0
Less: Imputed Interest	5.6
Total Lease Obligations	16.4
Less: Current Lease Obligations	4.8
Long-term Lease Obligations	11.6
Other Liabilities
Lessee, Lease, Description [Line Items]
Total Lease Obligations	16.4	$ 22.4
Other Current Liabilities
Lessee, Lease, Description [Line Items]
Less: Current Lease Obligations	4.8	5.9
Other Noncurrent Liabilities
Lessee, Lease, Description [Line Items]
Long-term Lease Obligations	$ 11.6	$ 16.5

Pension and Other Postretirement Benefit Plans - Assumptions Used to Determine Benefit Obligation and Net Periodic Benefit Costs (Details)

12 Months Ended

Dec. 31, 2021

Dec. 31, 2020

Dec. 31, 2019

Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]

Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Costs, Future Period

6.00%

Assumptions Used to Determine Benefit Obligation [Abstract]

Discount Rate

3.05%

2.62%

Rate of Compensation Increase

3.58%

3.61%

Assumptions Used to Determine Net Periodic Benefit Costs [Abstract]

Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate

2.87%

3.52%

4.67%

Expected Long-Term Return on Plan Assets

^[1]

6.50%

6.75%

7.25%

Rate of Compensation Increase

3.62%

4.06%

4.04%

Postretirement Health and Life [Member]

Assumptions Used to Determine Benefit Obligation [Abstract]

Discount Rate

3.09%

2.70%

Health Care Trend Rates [Abstract]

Trend Rate

5.66%

5.81%

Ultimate Trend Rate

4.50%

Year Ultimate Trend Rate Effective

2038

Assumptions Used to Determine Net Periodic Benefit Costs [Abstract]

Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate

2.70%

3.45%

4.47%

Expected Long-Term Return on Plan Assets

^[1]

5.85%

6.08%

6.51%

Postretirement Health and Life [Member] | Minimum [Member]

Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]

Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Costs, Future Period

4.80%

Postretirement Health and Life [Member] | Maximum [Member]

Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]

Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Costs, Future Period

6.00%

[1]	The expected long-term rates of return used to determine net periodic benefit expense for 2022 have been reduced to 6.00 percent for pension expense and 4.80 percent to 6.00 percent for postretirement health and life expense.

Income Tax Expense - Gross Unrecognized Income Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Gross Unrecognized Income Tax Benefits [Roll Forward]
Balance at January 1	$ 1.4	$ 1.4	$ 1.6
Additions for Tax Positions Related to the Current Year	0.0	0.1	0.1
Additions for Tax Positions Related to Prior Years	0.0	0.0	0.1
Reduction for Tax Positions Related to Prior Years	(0.1)	(0.1)	(0.4)
Lapse of Statute	0.0	0.0	0.0
Balance as of December 31	1.3	1.4	1.4
Unrecognized Tax Benefits that Would Impact Effective Tax Rate	0.6
Unrecognized Tax Benefits, Accrued Interest	0.0	0.0	0.0
Unrecognized Tax Benefits, Penalties	0.0	$ 0.0	$ 0.0
Material Changes to Unrecognized Tax Benefits Expected During Next 12 Months	$ 0.0

Regulatory Matters - Integrated Resource Plan (Details) - MW		3 Months Ended
	Oct. 01, 2021	Dec. 31, 2021	Feb. 01, 2021
Natural Gas-Fired [Member] \| Nemadji Trail Energy Center [Member]
Regulatory Matters [Line Items]
Generating Capacity Jointly Owned (MW)		600
Expected Output Entitlement (Percent)	20.00%	20.00%
MPUC [Member] \| Renewable Generation [Member] \| 2021 Integrated Resource Plan [Member]
Regulatory Matters [Line Items]
Generating Capacity (MW)			400

Short-Term and Long-Term Debt - Long-Term Debt (Details) $ in Millions	1 Months Ended	12 Months Ended
	Jan. 31, 2022 USD ($)	Dec. 31, 2021 USD ($) Years	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)
Debt Instrument [Line Items]
Long-Term Debt		$ 1,763.2	$ 1,593.2
Long-Term Debt - Unamortized Debt Issuance Costs		8.8
Debt Instrument [Abstract]
Long-Term Debt Maturing in 2022		214.5
Long-Term Debt Maturing in 2023		89.7
Long-Term Debt Maturing in 2024		74.4
Long-Term Debt Maturing in 2025		386.7
Long-Term Debt Maturing in 2026		77.2
Long-Term Debt Maturing Thereafter		1,143.9
Proceeds from Non-Controlling Interest - Net of Issuance Costs		90.9	$ 414.5	$ 103.8
Camp Ripley Financing [Member]
Debt Instrument [Abstract]
Annual Financing Payment		$ 1.4
Financing Renewal Term (Years) \| Years		2
Purchase Option		$ 4.0
First Mortgage Bonds - 2.50% Due August 2030 [Member]
Debt Instrument [Abstract]
Interest Rate		4.08%
First Mortgage Bonds - 4.47% Series Due 2049 [Member]
Debt Instrument [Abstract]
Interest Rate		4.47%
First Mortgage Bonds - 4.07% Series Due 2048 [Member]
Debt Instrument [Abstract]
Interest Rate		4.07%
ALLETE Senior Unsecured Notes 3.11% Due 2027 [Member]
Debt Instrument [Abstract]
Interest Rate		3.11%
First Mortgage Bonds - 2.50% Series Due 2030
Debt Instrument [Abstract]
Interest Rate		2.50%
First Mortgage Bonds - 3.30% Series Due 2050
Debt Instrument [Abstract]
Interest Rate		3.30%
Unsecured Term Loan Due In 2022
Debt Instrument [Abstract]
Unsecured Term Loan, Amount		$ 150.0
Debt Instrument, Description of Variable Rate Basis		LIBOR
Debt Instrument, Basis Spread on Variable Rate		0.75%
Debt Drawn Through Accordion Feature		$ 35.0
Unsecured Debt, Total Drawn on Loan		185.0
ALLETE Bonds 2.79% Series Due 2031
Debt Instrument [Abstract]
Proceeds from Issuance of First Mortgage Bond		$ 100.0
Interest Rate		2.79%
Subsequent Event [Member] \| Caddo [Member]
Debt Instrument [Abstract]
Proceeds from Non-Controlling Interest - Net of Issuance Costs	$ 183.0

Short-Term and Long-Term Debt (Tables)

12 Months Ended

Dec. 31, 2021

Debt Disclosure [Abstract]

Long-term Debt [Table Text Block]


Long-Term Debt
As of December 31	2021	2020
Millions
First Mortgage Bonds
4.85% Series Due 2021	—	$15.0
3.02% Series Due 2021	—	60.0
3.40% Series Due 2022	$75.0	75.0
6.02% Series Due 2023	75.0	75.0
3.69% Series Due 2024	60.0	60.0
4.90% Series Due 2025	30.0	30.0
5.10% Series Due 2025	30.0	30.0
3.20% Series Due 2026	75.0	75.0
5.99% Series Due 2027	60.0	60.0
3.30% Series Due 2028	40.0	40.0
4.08% Series Due 2029	70.0	70.0
3.74% Series Due 2029	50.0	50.0
2.50% Series Due 2030	46.0	46.0
3.86% Series Due 2030	60.0	60.0
2.79% Series Due 2031	100.0	—
5.69% Series Due 2036	50.0	50.0
6.00% Series Due 2040	35.0	35.0
5.82% Series Due 2040	45.0	45.0
4.08% Series Due 2042	85.0	85.0
4.21% Series Due 2043	60.0	60.0
4.95% Series Due 2044	40.0	40.0
5.05% Series Due 2044	40.0	40.0
4.39% Series Due 2044	50.0	50.0
4.07% Series Due 2048	60.0	60.0
4.47% Series Due 2049	30.0	30.0
3.30% Series Due 2050	94.0	94.0


ALLETE Clean Energy Unsecured Term Loan Variable Rate Due 2021	—	65.0
Armenia Mountain Senior Secured Notes 3.26% Due 2024	29.1	38.6
Industrial Development Variable Rate Demand Refunding Revenue Bonds Series 2006, Due 2025	27.8	27.8
Revolving Credit Facility Variable Rate Due 2025	145.0	—
Senior Unsecured Notes 2.65% Due 2025	150.0	150.0
Senior Unsecured Notes 3.11% Due 2027	80.0	80.0
SWL&P First Mortgage Bonds 4.15% Series Due 2028	15.0	15.0
SWL&P First Mortgage Bonds 4.14% Series Due 2048	12.0	12.0
Unsecured Term Loan Variable Rate Due 2021	—	40.0
Unsecured Term Loan Variable Rate Due 2022	110.0	—
Other Long-Term Debt, 2.16% – 4.58% Due 2022 – 2051	57.5	43.0
Unamortized Debt Issuance Costs	(9.0)	(9.5)
Total Long-Term Debt	1,977.4	1,796.9
Less: Due Within One Year	214.2	203.7
Net Long-Term Debt	$1,763.2	$1,593.2

Tabular disclosure of long-debt instruments or arrangements, including identification, terms, features, collateral requirements and other information necessary to a fair presentation. These are debt arrangements that originally required repayment more than twelve months after issuance or greater than the normal operating cycle of the entity, if longer.

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Quarterly Financial Data (Unaudited) (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended												12 Months Ended
	Dec. 31, 2021	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Selected Quarterly Financial Information [Abstract]
Operating Revenue	$ 399.0	$ 345.4	$ 335.6	$ 339.2	$ 320.4	$ 293.9	$ 243.2	$ 311.6	$ 304.6	$ 288.3	$ 290.4	$ 357.2	$ 1,419.2	$ 1,169.1	$ 1,240.5
Operating Income	50.0	31.1	28.2	42.0	36.4	41.6	12.7	60.2	49.8	37.0	36.2	56.8	151.3	150.9	179.8
Net Income Attributable to ALLETE	$ 61.9	$ 27.6	$ 27.9	$ 51.8	$ 47.1	$ 40.7	$ 20.1	$ 66.3	$ 49.7	$ 31.2	$ 34.2	$ 70.5	$ 169.2	$ 174.2	$ 185.6
Basic Earnings Per Share of Common Stock	$ 1.18	$ 0.53	$ 0.53	$ 0.99	$ 0.91	$ 0.78	$ 0.39	$ 1.28	$ 0.96	$ 0.60	$ 0.66	$ 1.37	$ 3.23	$ 3.36	$ 3.59
Diluted Earnings Per Share of Common Stock	$ 1.18	$ 0.53	$ 0.53	$ 0.99	$ 0.90	$ 0.78	$ 0.39	$ 1.28	$ 0.96	$ 0.60	$ 0.66	$ 1.37	$ 3.23	$ 3.35	$ 3.59

The amount of net income (loss) for the period per each share of common stock or unit outstanding during the reporting period.

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The portion of profit or loss for the period, net of income taxes, which is attributable to the parent.

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Amount of revenue recognized from goods sold, services rendered, insurance premiums, or other activities that constitute an earning process. Includes, but is not limited to, investment and interest income before deduction of interest expense when recognized as a component of revenue, and sales and trading gain (loss).

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Short-Term and Long-Term Debt - Schedule of Long-Term Debt (Details) - USD ($)
$ in Millions

Dec. 31, 2021

Dec. 31, 2020

Unamortized Debt Issuance Costs

^[1]

$ 1,986.4

$ 1,806.4

(9.0)

(9.5)

Total Long-Term Debt

1,977.4

1,796.9

Less: Due Within One Year

214.2

203.7

Net Long-Term Debt

$ 1,763.2

1,593.2

First Mortgage Bonds - 4.85% Series Due 2021 [Member]

4.85%

First Mortgage Bonds - 3.02% Series Due 2021 [Member]

$ 0.0

15.0

3.02%

First Mortgage Bonds - 3.40% Series Due 2022 [Member]

$ 0.0

60.0

3.40%

First Mortgage Bonds - 6.02% Series Due 2023 [Member]

$ 75.0

75.0

6.02%

First Mortgage Bonds - 3.69% Series Due 2024 [Member]

$ 75.0

75.0

3.69%

First Mortgage Bonds - 4.90% Series Due 2025 [Member]

$ 60.0

60.0

4.90%

First Mortgage Bonds - 5.10% Series Due 2025 [Member]

$ 30.0

30.0

5.10%

First Mortgage Bonds - 3.20% Series Due 2026 [Member]

$ 30.0

30.0

3.20%

First Mortgage Bonds - 5.99% Series Due 2027 [Member]

$ 75.0

75.0

5.99%

First Mortgage Bonds - 3.30% Series Due 2028 [Member]

$ 60.0

60.0

3.30%

First Mortgage Bonds - 2.50% Due August 2030 [Member]

$ 40.0

40.0

4.08%

First Mortgage Bonds - 3.74% Series Due 2029 [Member]

$ 70.0

70.0

3.74%

First Mortgage Bonds - 2.50% Series Due 2030

$ 50.0

50.0

2.50%

First Mortgage Bonds - 3.86% Series Due 2030 [Member]

$ 46.0

46.0

3.86%

First Mortgage Bonds - 2.79% Series Due 2031

$ 60.0

60.0

2.79%

First Mortgage Bonds - 5.69% Series Due 2036 [Member]

$ 100.0

0.0

5.69%

First Mortgage Bonds - 6.00% Series Due 2040 [Member]

$ 50.0

50.0

6.00%

First Mortgage Bonds - 5.82% Series Due 2040 [Member]

$ 35.0

35.0

5.82%

First Mortgage Bonds - 4.08% Series Due 2042 [Member]

$ 45.0

45.0

4.08%

First Mortgage Bonds - 4.21% Series Due 2043 [Member]

$ 85.0

85.0

4.21%

First Mortgage Bonds - 4.95% Series Due 2044 [Member]

$ 60.0

60.0

4.95%

First Mortgage Bonds - 5.05% Series Due 2044 [Member]

$ 40.0

40.0

5.05%

First Mortgage Bonds - 4.39% Series Due 2044 [Member]

$ 40.0

40.0

4.39%

First Mortgage Bonds - 4.07% Series Due 2048 [Member]

$ 50.0

50.0

4.07%

First Mortgage Bonds - 4.47% Series Due 2049 [Member]

$ 60.0

60.0

4.47%

First Mortgage Bonds - 3.30% Series Due 2050

$ 30.0

30.0

3.30%

ALLETE Clean Energy Unsecured Term Loan Variable Rate Due 2021

$ 94.0

94.0

Armenia Mountain Senior Secured Notes 3.26% Due 2024 [Member]

$ 0.0

65.0

3.26%

Industrial Development Variable Rate Demand Refunding Revenue Bonds Series 2006, Due 2025 [Member]

$ 29.1

38.6

Revolving Credit Facility Variable Rate Due 2025

27.8

Unsecured Senior Notes 2.65% Due 2025

$ 145.0

0.0

2.65%

ALLETE Senior Unsecured Notes 3.11% Due 2027 [Member]

$ 150.0

150.0

3.11%

SWL&P First Mortgage Bonds 4.15% Series Due 2028 [Member]

$ 80.0

80.0

4.15%

SWL&P First Mortgage Bonds 4.14% Series Due 2048 [Member]

$ 15.0

15.0

4.14%

Unsecured Term Loan Variable Rate Due 2021

$ 12.0

12.0

Unsecured Term Loan Variable Rate Due 2022

0.0

40.0

Other Long-Term Debt, 2.16% – 4.58% Due 2022 – 2051 [Member]

110.0

0.0

Other Long-Term Debt, 2.16% – 4.58% Due 2022 – 2051 [Member] | Minimum [Member]

$ 57.5

$ 43.0

Other Long-Term Debt, 2.16% – 4.58% Due 2022 – 2051 [Member] | Maximum [Member]

2.16%

4.58%

[1]	Excludes unamortized debt issuance costs.

Jointly-Owned Facilities and Assets (Details) $ in Millions	Dec. 31, 2021 USD ($) MW	Dec. 31, 2020 USD ($)
Jointly-Owned Facilities and Assets [Line Items]
Plant in Service	$ 783.7	$ 764.8
Accumulated Depreciation	329.6	304.8
Construction Work in Progress	30.1	15.0
Transmission [Member] \| Transmission Assets [Member]
Jointly-Owned Facilities and Assets [Line Items]
Plant in Service	101.0	101.0
Accumulated Depreciation	18.5	16.0
Construction Work in Progress	$ 0.0	$ 0.0
Transmission [Member] \| Transmission Assets [Member] \| Minimum [Member]
Jointly-Owned Facilities and Assets [Line Items]
Minnesota Power Ownership %	9.30%	9.30%
Transmission [Member] \| Transmission Assets [Member] \| Maximum [Member]
Jointly-Owned Facilities and Assets [Line Items]
Minnesota Power Ownership %	14.70%	14.70%
Boswell Unit 4 [Member] \| Jointly-Owned Electricity Generation Plant [Member]
Jointly-Owned Facilities and Assets [Line Items]
Minnesota Power Ownership %	80.00%	80.00%
Generating Capacity Jointly Owned (MW) \| MW	585
WPPI Energy Ownership %	20.00%
Plant in Service	$ 682.7	$ 663.8
Accumulated Depreciation	311.1	288.8
Construction Work in Progress	$ 30.1	$ 15.0

Commitments, Guarantees and Contingencies - Power Purchase Agreements (Details) MWh in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2021 USD ($) MWh MW	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)
Square Butte [Member] \| Square Butte PPA (expires 2026) [Member]
Power Purchase Agreements [Line Items]
PPA Counterparty Total Debt Outstanding \| $	$ 222.6
Cost of Purchased Power \| $	82.4	$ 79.5	$ 82.7
Pro Rata Share of PPA Counterparty Interest Expense \| $	$ 5.8	$ 7.1	$ 8.3
Square Butte [Member] \| Square Butte PPA (expires 2026) [Member] \| Square Butte Coal-fired Unit [Member]
Power Purchase Agreements [Line Items]
Generating Capacity Counterparty Owned (MW)	455
Minnesota Power Output Entitlement (Percent)	50.00%
PPA Annual Debt Service Obligation (Percentage)	50.00%
Manitoba Hydro [Member] \| Manitoba Hydro PPA (expires April 2022) [Member] \| Minimum [Member]
Power Purchase Agreements [Line Items]
Output Being Purchased (MWh) \| MWh	1,000,000
Manitoba Hydro [Member] \| Manitoba Hydro PPA (expires 2040) [Member]
Power Purchase Agreements [Line Items]
Output Being Purchased - Electric Energy (MW)	133
Manitoba Hydro [Member] \| Manitoba Hydro PPA (expires May 2035) [Member]
Power Purchase Agreements [Line Items]
Output Being Purchased - Electric Energy and Capacity (MW)	250
Nobles 2 [Member] \| Nobles 2 [Member]
Power Purchase Agreements [Line Items]
Output Being Purchased - Electric Energy and Capacity (MW)	250
Oliver Wind [Member] \| Oliver Wind I PPA [Member]
Power Purchase Agreements [Line Items]
Output Being Purchased - Electric Energy (MW)	50
Oliver Wind [Member] \| Oliver Wind II PPA [Member]
Power Purchase Agreements [Line Items]
Output Being Purchased - Electric Energy (MW)	48
Basin Electric Power Cooperative [Member] \| Basin Electric Cooperative PSA June 2022 - May 2023 [Member]
Power Purchase Agreements [Line Items]
Output Being Sold Electric - Capacity (MW)	75
Basin Electric Power Cooperative [Member] \| Basin Electric Cooperative PSA June 2023 - May 2025 [Member]
Power Purchase Agreements [Line Items]
Output Being Sold Electric - Capacity (MW)	125
Minnkota Power [Member] \| Square Butte PPA (expires 2026) [Member] \| Minnkota Sales Agreement [Member] \| Square Butte Coal-fired Unit [Member]
Power Purchase Agreements [Line Items]
Minnesota Power Output Entitlement (Percent)	28.00%	28.00%	28.00%
Silver Bay Power [Member] \| Silver Bay Power Self-Generation [Member]
Power Purchase Agreements [Line Items]
Energy Generation Owned (MW)	90
Calpine Corporation [Member] \| Calpine Corporation PPA [Member]
Power Purchase Agreements [Line Items]
Output Being Purchased - Electric Capacity (MW)	25
Great River Energy [Member] \| Great River Energy Power Sales Agreement (expires May 2025)
Power Purchase Agreements [Line Items]
Output Being Sold Electric - Capacity (MW)	100
Basin [Member] \| Basin Power Sales Agreement (expires May 2028) [Member]
Power Purchase Agreements [Line Items]
Output Being Sold Electric - Capacity (MW)	100
Oconto Electric Cooperative [Member] \| Oconto Electric Cooperative Power Sales Agreement [Member]
Power Purchase Agreements [Line Items]
Output Being Sold Electric - Energy and Capacity (MW)	25
2024-01-01 [Member] \| Square Butte [Member] \| Square Butte PPA (expires 2026) [Member] \| Square Butte Coal-fired Unit [Member]
Power Purchase Agreements [Line Items]
PPA Counterparty Annual Debt Service through 2026 \| $	$ 30.5
2021-01-01 [Member] \| Square Butte [Member] \| Square Butte PPA (expires 2026) [Member] \| Square Butte Coal-fired Unit [Member]
Power Purchase Agreements [Line Items]
PPA Counterparty Annual Debt Service through 2026 \| $	45.5
2025-01-01 [Member] \| Square Butte [Member] \| Square Butte PPA (expires 2026) [Member] \| Square Butte Coal-fired Unit [Member]
Power Purchase Agreements [Line Items]
PPA Counterparty Annual Debt Service through 2026 \| $	26.6
2026-01-01 \| Square Butte [Member] \| Square Butte PPA (expires 2026) [Member] \| Square Butte Coal-fired Unit [Member]
Power Purchase Agreements [Line Items]
PPA Counterparty Annual Debt Service through 2026 \| $	40.1
2022-01-01 [Member] \| Square Butte [Member] \| Square Butte PPA (expires 2026) [Member] \| Square Butte Coal-fired Unit [Member]
Power Purchase Agreements [Line Items]
PPA Counterparty Annual Debt Service through 2026 \| $	45.5
2023-01-01 [Member] \| Square Butte [Member] \| Square Butte PPA (expires 2026) [Member] \| Square Butte Coal-fired Unit [Member]
Power Purchase Agreements [Line Items]
PPA Counterparty Annual Debt Service through 2026 \| $	$ 45.5

Common Stock and Earnings Per Share - Reconciliation of Basic and Diluted Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended												12 Months Ended
	Dec. 31, 2021	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Earnings Per Share - Basic [Abstract]
Net Income Attributable to ALLETE	$ 61.9	$ 27.6	$ 27.9	$ 51.8	$ 47.1	$ 40.7	$ 20.1	$ 66.3	$ 49.7	$ 31.2	$ 34.2	$ 70.5	$ 169.2	$ 174.2	$ 185.6
Average Common Shares													52.4	51.9	51.6
Earnings Per Share	$ 1.18	$ 0.53	$ 0.53	$ 0.99	$ 0.91	$ 0.78	$ 0.39	$ 1.28	$ 0.96	$ 0.60	$ 0.66	$ 1.37	$ 3.23	$ 3.36	$ 3.59
Earnings Per Share - Diluted [Abstract]
Net Income Attributable to ALLETE													$ 169.2	$ 174.2	$ 185.6
Average Common Shares													52.5	51.9	51.7
Earnings Per Share	$ 1.18	$ 0.53	$ 0.53	$ 0.99	$ 0.90	$ 0.78	$ 0.39	$ 1.28	$ 0.96	$ 0.60	$ 0.66	$ 1.37	$ 3.23	$ 3.35	$ 3.59
Dilutive Securities (Shares)													0.1	0.0	0.1

The amount of net income (loss) for the period per each share of common stock or unit outstanding during the reporting period.

The portion of profit or loss for the period, net of income taxes, which is attributable to the parent.

Amount, after deduction of tax, noncontrolling interests, dividends on preferred stock and participating securities, and addition from assumption of issuance of common shares for dilutive potential common shares; of income (loss) available to common shareholders.

Fair Value of Financial Instruments [Line Items]

Consolidated Balance Sheet Parentheticals - USD ($) shares in Millions, $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Accounts Receivable [Abstract]
Accounts Receivable, Allowance	$ 1.8	$ 2.5
Common Stock [Abstract]
Common Stock, Par Value Per Share	$ 0	$ 0
Common Stock, Shares Authorized	80.0	80.0
Common Stock, Shares Issued	53.2	52.1
Common Stock, Shares Outstanding	53.2	52.1

Fair Value - Financial Instruments (Details) - USD ($)
$ in Millions

Dec. 31, 2021

Dec. 31, 2020

Short-Term and Long-Term Debt - Carrying Amount

^[1]

$ 1,986.4

$ 1,806.4

Level 2 [Member]

Fair Value of Financial Instruments [Line Items]

Short-Term and Long-Term Debt - Fair Value

^[1]

$ 2,192.6

$ 2,122.0

[1]	Excludes unamortized debt issuance costs.

Business Segment (Tables)

12 Months Ended

Dec. 31, 2021

Segment Reporting [Abstract]

Schedule of Segment Reporting Information, by Segment [Table Text Block]


Year Ended December 31	2021	2020	2019
Millions
Operating Revenue
Residential	$160.8	$140.7	$139.6
Commercial	168.6	139.5	145.7
Municipal	52.0	41.2	48.6
Industrial	565.5	432.8	476.4
Other Power Suppliers	168.7	138.8	153.7
CIP Financial Incentive (a)	2.4	2.4	2.8
Other	109.9	91.9	75.6
Total Regulated Operations	1,227.9	987.3	1,042.4



ALLETE Clean Energy
Long-term PSA	75.5	68.3	48.0

Other	11.4	11.3	11.6
Total ALLETE Clean Energy	86.9	79.6	59.6

U.S. Water Services (b)
Point-in-time	—	—	19.0
Contract	—	—	9.2
Capital Project	—	—	5.2
Total U.S. Water Services	—	—	33.4

Corporate and Other
Long-term Contract	84.4	86.0	82.8
Other	20.0	16.2	22.3
Total Corporate and Other	104.4	102.2	105.1
Total Operating Revenue	$1,419.2	$1,169.1	$1,240.5
Net Income (Loss) Attributable to ALLETE (c)
Regulated Operations	$129.1	$136.3	$154.4


ALLETE Clean Energy	26.3	29.9	12.4
U.S. Water Services	—	—	(1.1)

Corporate and Other (b)(d)	13.8	8.0	19.9
Total Net Income Attributable to ALLETE	$169.2	$174.2	$185.6

(a) See Note 4. Regulatory Matters.

(b) In 2019, ALLETE sold U.S. Water Services. The Company recognized a gain on the sale of $13.2 million after-tax which is reflected in Corporate and Other. (See Note 1. Operations and Significant Accounting Policies.)

(c) Includes interest expense resulting from intercompany loan agreements and allocated to certain subsidiaries. The amounts are eliminated in consolidation.

(d) In 2021, South Shore Energy sold a portion of its undivided ownership interest in NTEC to Basin. The closing of the transaction resulted in the recognition of an approximately $8.5 million after-tax gain which is reflected in Corporate and Other. (See Note 1. Operations and Significant Accounting Policies.)


Year Ended December 31	2021	2020	2019
Millions
Depreciation and Amortization
Regulated Operations	$170.7	$166.9	$159.4


ALLETE Clean Energy	49.2	37.9	26.8
U.S. Water Services	—	—	2.3

Corporate and Other	11.8	13.0	13.5
Total Depreciation and Amortization	$231.7	$217.8	$202.0




Interest Expense (a)
Regulated Operations	$57.3	$58.5	$58.9


ALLETE Clean Energy	1.5	2.2	2.8
U.S. Water Services	—	—	0.2

Corporate and Other	13.2	13.2	8.0

Eliminations	(2.9)	(8.3)	(5.0)
Total Interest Expense	$69.1	$65.6	$64.9
Equity Earnings
Regulated Operations	$21.3	$22.3	$21.7
Corporate and Other	(1.3)	(0.2)	—
Total Equity Earnings	$20.0	$22.1	$21.7
Income Tax Expense (Benefit)
Regulated Operations	$(16.6)	$(19.4)	$(7.1)


ALLETE Clean Energy	(16.6)	(19.1)	(11.9)
U.S. Water Services	—	—	(0.4)

Corporate and Other (b)	6.3	(1.0)	12.8
Total Income Tax Benefit	$(26.9)	$(39.5)	$(6.6)

(a) Includes interest expense resulting from intercompany loan agreements and allocated to certain subsidiaries. The amounts are eliminated in consolidation.

(b) In 2019, ALLETE sold U.S. Water Services. The Company recognized income tax expense of $10.4 million for the gain on sale of U.S. Water Services which is reflected in Corporate and Other. (See Note 1. Operations and Significant Accounting Policies.)


As of December 31	2021	2020
Millions
Assets
Regulated Operations	$4,289.4	$4,196.8


ALLETE Clean Energy	1,719.4	1,483.3


Corporate and Other	426.2	404.5
Total Assets	$6,435.0	$6,084.6
Capital Expenditures
Regulated Operations	$166.8	$133.7


ALLETE Clean Energy	269.9	507.8


Corporate and Other	39.7	15.7
Total Capital Expenditures	$476.4	$657.2

Income Tax Expense - NOL and Tax Credit Carryforwards (Details) - USD ($)
$ in Millions

Dec. 31, 2021

Dec. 31, 2020

Federal [Member]

NOL and Tax Credit Carryforwards [Line Items]

NOL Carryforwards

^[1]

$ 177.3

$ 197.5

Tax Credit Carryforwards

416.4

362.9

Tax Credit Carryforwards, Valuation Allowance

0.0

NOL Carryforwards, Valuation Allowance

0.0

State [Member]

NOL and Tax Credit Carryforwards [Line Items]

NOL Carryforwards

^[1]

506.9

270.1

Tax Credit Carryforwards

^[2]

24.2

23.4

Tax Credit Carryforwards, Valuation Allowance

$ 68.6

$ 69.4

[1]	Pre-tax amounts.
[2]	Net of a $68.6 million valuation allowance as of December 31, 2021 ($69.4 million as of December 31, 2020).

Business Segments

12 Months Ended

Dec. 31, 2021

Segment Reporting [Abstract]

Segment Reporting Disclosure [Text Block]

BUSINESS SEGMENTS

We present three reportable segments: Regulated Operations, ALLETE Clean Energy, and U.S. Water Services. We measure performance of our operations through budgeting and monitoring of contributions to consolidated net income by each business segment.

Regulated Operations includes three operating segments which consist of our regulated utilities, Minnesota Power and SWL&P, as well as our investment in ATC. ALLETE Clean Energy is our business focused on developing, acquiring and operating clean and renewable energy projects. U.S. Water Services was our integrated water management company, which reflects operating results until it was sold in March 2019. We also present Corporate and Other which includes two operating segments, BNI Energy, our coal mining operations in North Dakota, and ALLETE Properties, our legacy Florida real estate investment, along with our investment in Nobles 2, South Shore Energy, our non-rate regulated, Wisconsin subsidiary developing NTEC, other business development and corporate expenditures, unallocated interest expense, a small amount of non-rate base generation, approximately 4,000 acres of land in Minnesota, and earnings on cash and investments.

NOTE 13. BUSINESS SEGMENTS (Continued)


Year Ended December 31	2021	2020	2019
Millions
Operating Revenue
Residential	$160.8	$140.7	$139.6
Commercial	168.6	139.5	145.7
Municipal	52.0	41.2	48.6
Industrial	565.5	432.8	476.4
Other Power Suppliers	168.7	138.8	153.7
CIP Financial Incentive (a)	2.4	2.4	2.8
Other	109.9	91.9	75.6
Total Regulated Operations	1,227.9	987.3	1,042.4



ALLETE Clean Energy
Long-term PSA	75.5	68.3	48.0

Other	11.4	11.3	11.6
Total ALLETE Clean Energy	86.9	79.6	59.6

U.S. Water Services (b)
Point-in-time	—	—	19.0
Contract	—	—	9.2
Capital Project	—	—	5.2
Total U.S. Water Services	—	—	33.4

Corporate and Other
Long-term Contract	84.4	86.0	82.8
Other	20.0	16.2	22.3
Total Corporate and Other	104.4	102.2	105.1
Total Operating Revenue	$1,419.2	$1,169.1	$1,240.5
Net Income (Loss) Attributable to ALLETE (c)
Regulated Operations	$129.1	$136.3	$154.4


ALLETE Clean Energy	26.3	29.9	12.4
U.S. Water Services	—	—	(1.1)

Corporate and Other (b)(d)	13.8	8.0	19.9
Total Net Income Attributable to ALLETE	$169.2	$174.2	$185.6

(a) See Note 4. Regulatory Matters.

(c) Includes interest expense resulting from intercompany loan agreements and allocated to certain subsidiaries. The amounts are eliminated in consolidation.

NOTE 13. BUSINESS SEGMENTS (Continued)


Year Ended December 31	2021	2020	2019
Millions
Depreciation and Amortization
Regulated Operations	$170.7	$166.9	$159.4


ALLETE Clean Energy	49.2	37.9	26.8
U.S. Water Services	—	—	2.3

Corporate and Other	11.8	13.0	13.5
Total Depreciation and Amortization	$231.7	$217.8	$202.0




Interest Expense (a)
Regulated Operations	$57.3	$58.5	$58.9


ALLETE Clean Energy	1.5	2.2	2.8
U.S. Water Services	—	—	0.2

Corporate and Other	13.2	13.2	8.0

Eliminations	(2.9)	(8.3)	(5.0)
Total Interest Expense	$69.1	$65.6	$64.9
Equity Earnings
Regulated Operations	$21.3	$22.3	$21.7
Corporate and Other	(1.3)	(0.2)	—
Total Equity Earnings	$20.0	$22.1	$21.7
Income Tax Expense (Benefit)
Regulated Operations	$(16.6)	$(19.4)	$(7.1)


ALLETE Clean Energy	(16.6)	(19.1)	(11.9)
U.S. Water Services	—	—	(0.4)

Corporate and Other (b)	6.3	(1.0)	12.8
Total Income Tax Benefit	$(26.9)	$(39.5)	$(6.6)

(a) Includes interest expense resulting from intercompany loan agreements and allocated to certain subsidiaries. The amounts are eliminated in consolidation.


As of December 31	2021	2020
Millions
Assets
Regulated Operations	$4,289.4	$4,196.8


ALLETE Clean Energy	1,719.4	1,483.3


Corporate and Other	426.2	404.5
Total Assets	$6,435.0	$6,084.6
Capital Expenditures
Regulated Operations	$166.8	$133.7


ALLETE Clean Energy	269.9	507.8


Corporate and Other	39.7	15.7
Total Capital Expenditures	$476.4	$657.2

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
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-Section 50
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Reference 2: http://www.xbrl.org/2003/role/disclosureRef
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Recurring Fair Value Measures [Table Text Block]

Fair Value (Tables)

12 Months Ended

Dec. 31, 2021

Fair Value Disclosures [Abstract]


	Fair Value as of December 31, 2021
Recurring Fair Value Measures	Level 1	Level 2	Level 3	Total
Millions
Assets:
Investments (a)
Available-for-sale – Equity Securities	$8.9	—	—	$8.9
Available-for-sale – Corporate and Governmental Debt Securities (b)	—	$6.2	—	6.2
Cash Equivalents	2.5	—	—	2.5
Total Fair Value of Assets	$11.4	$6.2	—	$17.6

Liabilities:
Deferred Compensation (c)	—	$18.0	—	$18.0

Total Fair Value of Liabilities	—	$18.0	—	$18.0
Total Net Fair Value of Assets (Liabilities)	$11.4	$(11.8)	—	$(0.4)

(a)Included in Other Non-Current Assets on the Consolidated Balance Sheet.

(c)Included in Other Non-Current Liabilities on the Consolidated Balance Sheet.


	Fair Value as of December 31, 2020
Recurring Fair Value Measures	Level 1	Level 2	Level 3	Total
Millions
Assets:
Investments (a)
Available-for-sale – Equity Securities	$7.2	—	—	$7.2
Available-for-sale – Corporate and Governmental Debt Securities	—	$10.4	—	10.4
Cash Equivalents	5.5	—	—	5.5
Total Fair Value of Assets	$12.7	$10.4	—	$23.1

Liabilities: (b)
Deferred Compensation	—	$21.0	—	$21.0

Total Fair Value of Liabilities	—	$21.0	—	$21.0
Total Net Fair Value of Assets (Liabilities)	$12.7	$(10.6)	—	$2.1

(a)Included in Other Non-Current Assets on the Consolidated Balance Sheet.

(b)Included in Other Non-Current Liabilities on the Consolidated Balance Sheet.

Financial Instruments [Table Text Block]


Financial Instruments	Carrying Amount	Fair Value
Millions
Short-Term and Long-Term Debt (a)
December 31, 2021	$1,986.4	$2,192.6
December 31, 2020	$1,806.4	$2,122.0

(a) Excludes unamortized debt issuance costs.

Employee Stock and Incentive Plans (Tables)

12 Months Ended

Dec. 31, 2021

Share-based Payment Arrangement [Abstract]

Share-Based Compensation Expense [Table Text Block]

The following share-based compensation expense amounts were recognized in our Consolidated Statement of Income for the periods presented.


Share-Based Compensation Expense
Year Ended December 31	2021	2020	2019
Millions

Performance Shares	$2.0	$2.2	$2.3
Restricted Stock Units	1.0	0.9	0.8
Total Share-Based Compensation Expense	$3.0	$3.1	$3.1
Income Tax Benefit	$0.9	$0.9	$0.9

Performance Shares [Table Text Block]

Performance Shares. The following table presents information regarding our non-vested performance shares.


	2021		2020		2019
	Number of Shares	Weighted- Average Grant Date Fair Value	Number of Shares	Weighted- Average Grant Date Fair Value	Number of Shares	Weighted- Average Grant Date Fair Value
Non-vested as of January 1	85,284	$80.73	99,585	$72.78	129,693	$66.12
Granted (a)	33,304	$73.25	25,763	$83.17	60,747	$63.89
Awarded	—	—	(25,304)	$62.03	(75,943)	$53.44
Unearned Grant Award	(33,375)	$86.09	(13,625)	$62.03	—	—
Forfeited	(4,552)	$74.05	(1,135)	$79.81	(14,912)	$77.14
Non-vested as of December 31	80,661	$75.80	85,284	$80.73	99,585	$72.78

(a) Shares granted include accrued dividends.

Restricted Stock Units [Table Text Block]

Restricted Stock Units. The following table presents information regarding our available restricted stock units.


	2021		2020		2019
	Number of Shares	Weighted- Average Grant Date Fair Value	Number of Shares	Weighted- Average Grant Date Fair Value	Number of Shares	Weighted- Average Grant Date Fair Value
Available as of January 1	37,482	$77.64	39,943	$69.30	49,771	$60.74
Granted (a)	16,251	$64.97	15,169	$83.48	13,927	$74.93
Awarded	(23,631)	$74.53	(17,193)	$63.41	(21,110)	$52.44
Forfeited	(1,961)	$74.52	(437)	$77.52	(2,645)	$72.43
Available as of December 31	28,141	$73.16	37,482	$77.64	39,943	$69.30

(a) Shares granted include accrued dividends.

Property, Plant and Equipment (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2021

Dec. 31, 2020

Asset Retirement Obligation [Roll Forward]

$ 5,100.2

$ 4,840.8

Beginning Obligation

166.6

160.3

Accretion

8.8

8.3

Liabilities Recognized

4.5

1.4

Liabilities Settled

(5.2)

(3.6)

Revisions in Estimated Cash Flows

9.8

0.2

Ending Obligation

184.5

166.6

Regulated Operations [Member]

Property, Plant and Equipment in Service

5,028.7

4,972.3

Construction Work in Progress

108.7

79.4

Accumulated Depreciation

(1,834.6)

(1,758.0)

Regulated Operations [Member] | Generation [Member] | Minimum [Member]

$ 3,302.8

3,293.7

Regulated Operations [Member] | Generation [Member] | Maximum [Member]

2 years

Regulated Operations [Member] | Transmission [Member] | Minimum [Member]

50 years

Regulated Operations [Member] | Transmission [Member] | Maximum [Member]

50 years

Regulated Operations [Member] | Distribution [Member] | Minimum [Member]

75 years

Regulated Operations [Member] | Distribution [Member] | Maximum [Member]

18 years

ALLETE Clean Energy [Member]

70 years

Property, Plant and Equipment in Service

$ 1,716.9

1,275.4

Construction Work in Progress

79.9

261.0

Accumulated Depreciation

(149.0)

(112.9)

ALLETE Clean Energy [Member] | Minimum [Member]

$ 1,647.8

1,423.5

ALLETE Clean Energy [Member] | Maximum [Member]

5 years

Corporate and Other [Member]

35 years

Property, Plant and Equipment in Service

^[1]

$ 267.1

240.5

Construction Work in Progress

^[1]

19.8

9.6

Accumulated Depreciation

^[1]

(137.3)

(126.5)

Corporate and Other [Member] | Minimum [Member]

^[1]

$ 149.6

$ 123.6

Corporate and Other [Member] | Maximum [Member]

3 years

Income Tax Expense [Text Block]

50 years

[1]	Primarily includes BNI Energy and a small amount of non-rate base generation.

Income Tax Expense

12 Months Ended

Dec. 31, 2021

Income Tax Disclosure [Abstract]

INCOME TAX EXPENSE


Income Tax Expense
Year Ended December 31	2021	2020	2019
Millions
Current Income Tax Expense (a)
Federal	—	—	—
State	—	—	$0.1
Total Current Income Tax Expense	—	—	$0.1
Deferred Income Tax Expense (Benefit)
Federal (b)	$(37.2)	$(48.8)	$(27.8)

State	10.8	9.8	21.7

Investment Tax Credit Amortization	(0.5)	(0.5)	(0.6)
Total Deferred Income Tax Expense (Benefit)	$(26.9)	$(39.5)	$(6.7)
Total Income Tax Expense (Benefit)	$(26.9)	$(39.5)	$(6.6)

(b)For the years ended December 31, 2021, 2020 and 2019, the federal tax benefit is primarily due to production tax credits.

NOTE 10. INCOME TAX EXPENSE (Continued)


Reconciliation of Taxes from Federal Statutory
Rate to Total Income Tax Expense
Year Ended December 31	2021		2020		2019
Millions
Income Before Non-Controlling Interest and Income Taxes	$110.9		$122.1		$178.9
Statutory Federal Income Tax Rate	21	%	21	%	21	%
Income Taxes Computed at Statutory Federal Rate	$23.3		$25.6		$37.6
Increase (Decrease) in Tax Due to:
State Income Taxes – Net of Federal Income Tax Benefit	8.6		7.7		17.2


Production Tax Credits	(53.5)		(62.7)		(50.7)
Regulatory Differences – Excess Deferred Tax Benefit (a)	(9.5)		(9.9)		(8.8)
U.S. Water Services Sale of Stock Basis Difference	—		—		1.7

Non-Controlling Interest	6.3		2.7		—
Share-Based Compensation	0.5		—		—
Other	(2.6)		(2.9)		(3.6)
Total Income Tax Expense (Benefit)	$(26.9)		$(39.5)		$(6.6)

(a)Excess deferred income taxes are being returned to customers under both the Average Rate Assumption Method and amortization periods as approved by regulators. (See Note 4. Regulatory Matters.)

The effective tax rate was a benefit of 24.3 percent for 2021 (benefit of 32.4 percent for 2020; benefit of 3.7 percent for 2019). The 2021 effective tax rate was primarily impacted by production tax credits and non-controlling interests in subsidiaries. The 2020 effective tax rate was primarily impacted by production tax credits. The 2019 effective tax rate was primarily impacted by production tax credits and the gain on sale of U.S. Water Services.


Deferred Income Tax Assets and Liabilities
As of December 31	2021	2020
Millions
Deferred Income Tax Assets
Employee Benefits and Compensation	$44.5	$67.6
Property-Related	54.8	61.4
NOL Carryforwards	67.5	60.7
Tax Credit Carryforwards	509.1	455.7
Power Sales Agreements	16.5	20.1
Regulatory Liabilities	101.5	107.7
Other	—	22.4
Gross Deferred Income Tax Assets	793.9	795.6
Deferred Income Tax Asset Valuation Allowance	(69.0)	(69.9)
Total Deferred Income Tax Assets	$724.9	$725.7
Deferred Income Tax Liabilities
Property-Related	$680.8	$691.5
Regulatory Asset for Benefit Obligations	54.9	71.5
Unamortized Investment Tax Credits	30.5	31.1
Partnership Basis Differences	106.3	86.7
Regulatory Assets	30.0	32.6
Other	8.1	8.0
Total Deferred Income Tax Liabilities	$910.6	$921.4
Net Deferred Income Taxes (a)	$185.7	$195.7

(a)Recorded as a net long-term Deferred Income Tax liability on the Consolidated Balance Sheet.

NOTE 10. INCOME TAX EXPENSE (Continued)


NOL and Tax Credit Carryforwards
As of December 31	2021	2020
Millions
Federal NOL Carryforwards (a)	$177.3	$197.5
Federal Tax Credit Carryforwards	$416.4	$362.9
State NOL Carryforwards (a)	$506.9	$270.1
State Tax Credit Carryforwards (b)	$24.2	$23.4

(a)Pre-tax amounts.

(b)Net of a $68.6 million valuation allowance as of December 31, 2021 ($69.4 million as of December 31, 2020).

The federal NOL and tax credit carryforward periods expire between 2030 and 2042. We expect to fully utilize the federal NOL and federal tax credit carryforwards; therefore, no federal valuation allowance has been recognized as of December 31, 2021. The state NOL and tax credit carryforward periods expire between 2022 and 2045. We have established a valuation allowance against certain state NOL and tax credits that we do not expect to utilize before their expiration.


Gross Unrecognized Income Tax Benefits	2021	2020	2019
Millions
Balance at January 1	$1.4	$1.4	$1.6
Additions for Tax Positions Related to the Current Year	—	0.1	0.1
Additions for Tax Positions Related to Prior Years	—	—	0.1
Reductions for Tax Positions Related to Prior Years	(0.1)	(0.1)	(0.4)

Lapse of Statute	—	—	—
Balance as of December 31	$1.3	$1.4	$1.4

Unrecognized tax benefits are the differences between a tax position taken or expected to be taken in a tax return and the benefit recognized and measured pursuant to the “more-likely-than-not” criteria. The unrecognized tax benefit balance includes permanent tax positions which, if recognized would affect the annual effective income tax rate. In addition, the unrecognized tax benefit balance includes temporary tax positions for which the ultimate deductibility is highly certain but for which there is uncertainty about the timing of such deductibility. A change in the period of deductibility would not affect the effective tax rate but would accelerate the payment of cash to the taxing authority to an earlier period. The gross unrecognized tax benefits as of December 31, 2021, included $0.6 million of net unrecognized tax benefits which, if recognized, would affect the annual effective income tax rate.

As of December 31, 2021, we had no accrued interest (none as of December 31, 2020, and 2019) related to unrecognized tax benefits included on the Consolidated Balance Sheet due to our NOL carryforwards. We classify interest related to unrecognized tax benefits as interest expense and tax-related penalties in operating expenses on the Consolidated Statement of Income. Interest expense related to unrecognized tax benefits on the Consolidated Statement of Income was immaterial in 2021, 2020 and 2019. There were no penalties recognized in 2021, 2020 or 2019. The unrecognized tax benefit amounts have been presented as reductions to the tax benefits associated with NOL and tax credit carryforwards on the Consolidated Balance Sheet.

No material changes to unrecognized tax benefits are expected during the next 12 months.

ALLETE and its subsidiaries file a consolidated federal income tax return as well as combined and separate state income tax returns in various jurisdictions. ALLETE has no open federal or state audits, and is no longer subject to federal examination for years before 2018 or state examination for years before 2017.

The entire disclosure for income taxes. Disclosures may include net deferred tax liability or asset recognized in an enterprise's statement of financial position, net change during the year in the total valuation allowance, approximate tax effect of each type of temporary difference and carryforward that gives rise to a significant portion of deferred tax liabilities and deferred tax assets, utilization of a tax carryback, and tax uncertainties information.

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Common Stock and Earnings Per Share - Summary of Common Stock (Details) - USD ($) shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Summary of Common Stock [Line Items]
Balance, Shares	53,200	52,100
Common Stock [Member]
Summary of Common Stock [Line Items]
Balance, Shares	53,220	52,085	51,679	51,509
Balance, Equity	$ 1,536.7	$ 1,460.9	$ 1,436.7	$ 1,428.5
Employee Stock Purchase Plan, Shares	17	13	8
Employee Stock Purchase Plan, Equity	$ 0.8	$ 0.7	$ 0.7
Invest Direct, Shares	263	309	38
Invest Direct, Equity	$ 17.5	$ 18.3	$ 3.0
Options and Stock Awards, Shares	49	35	85
Options and Stock Awards, Equity	$ 3.4	$ 2.2	$ 1.3
Contributions to RSOP, Shares	24	49	39
Contributions to RSOP, Equity	$ 3.1	$ 3.0	$ 3.2
Common Stock Issued	$ 51.0
Equity Issuance Program, Shares	782	0	0
Equity Issuance Program Shares Authorized			13,600
Equity Issuance Program Shares Available for Issuance	2,100
Common Stock [Member] \| PIE Shares
Summary of Common Stock [Line Items]
Equity Issuance Program, Shares	800

Consolidated Statement of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Comprehensive Income [Abstract]
Net Income	$ 137.8	$ 161.6	$ 185.5
Other Comprehensive Income (Loss) [Abstract]
Unrealized Gain (Loss) on Securities - Net of Income Tax Expense (Benefit) of $(0.1), $0.1 and $0.1	(0.1)	0.1	0.2
Defined Benefit Pension and Other Postretirement Benefit Plans - Net of Income Tax Expense (Benefit) of $3.0, $(3.1) and $1.4	7.4	(7.6)	3.5
Total Other Comprehensive Income (Loss)	7.3	(7.5)	3.7
Total Comprehensive Income	145.1	154.1	189.2
Net Loss Attributable to Non-Controlling Interest	(31.4)	(12.6)	(0.1)
Total Comprehensive Income Attributable to ALLETE	$ 176.5	$ 166.7	$ 189.3

Amount after tax of increase (decrease) in equity from transactions and other events and circumstances from net income (loss) and other comprehensive income (loss), attributable to noncontrolling interests. Excludes changes in equity resulting from investments by owners and distributions to owners.

Amount after tax of increase (decrease) in equity from transactions and other events and circumstances from net income and other comprehensive income. Excludes changes in equity resulting from investments by owners and distributions to owners.

Amount after tax and reclassification adjustments of other comprehensive income (loss).

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